JPS58156690A - Well head system in sea - Google Patents

Abstract

(57) [Summary] This bulletin contains application data before electronic filing, so abstract data is not recorded.

Description

[Detailed description of the invention] The present invention relates to an underwater wellhead V-stage.

More specifically, the present invention relates to a method and apparatus for supporting, retaining and securing casing hangers within a well head, and as drilling operations are increasingly carried out with frame bars, operating pressures are increasing. Regarding the O well, recently, the working pressure is said to reach 1054.7 min/d (15,000 psi) OjI pressure. A new subsea wellhead system is needed to address the unique interstitial conditions associated with subsea drilling operations under such high pressures. Working pressure is 1054.7#/ad (15,000psi
Currently, there are wells reaching 081g in Canada and 0911g in the North Sea (
It has been drilled underwater over 300 feet (300 feet). This type of drilling work is generally accompanied by a floating vessel, which includes a blowout prevention mechanism located above the mud on the seabed, a well head (KM), and a burrow correction device for the wellhead and drill pipe. This blowout prevention suit can be attached to a 508cm (20 inch) OWKII for general fishing. A quick release *@ is arranged at the top of this blowout prevention stack. An indirect dilator is used to enable the movement of ships. Under these circumstances, 1054.7 official
Two problems arise when operating subsea wellhead systems at zero working pressures of 15,000 pm. That is, 1
One is the problem of the support shoulder located within the well head that supports the casing and pressure load, and the other is the function of the support shoulder located between the casing hanger and the well head that withstands the working pressure and suppresses the pressure within this pressure range. This is a problem with the sealing mechanism.

Traditionally, wellheads have been fitted with suitable landing support scents for successive casing hangers. However, as pressures increase and multiple O casings and tube strings are supported within a landed silanyl head, the small support shoulders have the disadvantage of not supporting the load sufficiently. Obviously, the solution to this problem would be to make the support shoulder larger to support the casing and pressure load, but the support shoulder is large and protrudes due to the large flow of the well head. Even if I tried to approach the casing under the well head for the side valve, I would be blocked. In the early days of offshore procedures, 425.45W (16
Under-reaming was required for the subsea well head S/stem with a diameter of '/4 inch). Well, in this era,
Most floating type side valves 111111 have 425.45 rin (165/4 inches) of blowout prevention wIII! ] was installed, and the previously required two stacks (5
0811 (20 inches) and 346 sm (13s/s
inch)) and two live devices are no longer required.

Well head system fi351.55#/d (500
0 psi) to 703.1/d (10,000 psi)
) of 703.1 mm/l:d (10,000 psi) of 476.251 (18'/4 inch)
) The support shoulder supports the casing and the pressure load.
As N is released, the casing under the well head housing becomes completely accessible.

The large mackerel of 2 Homare H is a V-ru mechanism. This V-ru mechanism is 1054.74/d (15,000p Hatake 1) C1
Gravity, hydraulic pressure, and torque are the available sources of energy for driving this overhead structure, which must be capable of withstanding and retaining the operating pressure. Zero gravity is most undesirable since each sealing mechanism requires a separate amount of energy for positioning and driving. This is because the increased width is difficult to handle on the training floor of the side valve collar that applies gravity, and it takes time and effort. When hydraulic pressure is applied through the side valve pipe, a pull fin facility is required to run the dart from the hydraulic source to the actuating seal drive device and to retrieve the dart. In addition, if you do not use darts, the "wet string" in the side valve pipe is very troublesome to handle and is not well received by workers.
When a single-trip case hanger construction method is used for the V-ru mechanism drive device, the welding fluid causes an interlayer in the hydraulic device used for rounding that drives the V-ru mechanism. There are also maintenance issues. To drive the seal mechanism
14 The preferred method is torque, but there is a limit to the amount of torque that can be transmitted because friction loss occurs from the sea surface to the live pipe, blowout prevention stack, off-location 5f1 line, various threaded parts, and the drilled pipe.

The subsea wellhead system according to the invention overcomes the drawbacks of the prior art and has a number of advantages.

The Oka system has a simple structure, the number of parts is less than 5o, H, Sf.
The 1ml system is mainly based on a single-trip method, but a multi-trip method can also be used.

All hangers are interchangeable on the outer 9#, so they can be used in relatively low positions - the sealing elements are also interchangeable and can be energized to pressures above the expected wellbore Taisho.

Backup v-le%fl! Can be used. The seal is not one that releases energy when pressure is applied. Hanga don't use lockdown! The seal element can perform a sufficient sealing function even when the hanger is assembled at a high position.

The housing support sheet is 272160 without exceeding the material sieve ff10150% in the compressed form 11
Supports 0# (6,000,000 pounds) (working pressure coupler skating weight or test pressure) or more. Well head is 444.5111g (17'/2 inch)
Pass the bit of vk. It is not intended in this invention to assemble two types of seats at once or two seats at a time; however, the heaving support seat is designed to prevent debris from collecting in the side valves. f) There is no sensing effect on the debris that collects when feeding the housing.Furthermore, the housing sate F-) does not require a separate trip mechanism and does not require a snap ring to be inserted into the hole. There is no such thing as dragging it down.

Hangarholtdown is 907200# (2,000,0
00 bond). In addition, Hunger Holtdown is
It has a structure that allows it to actively and mechanically retreat when recovering the casing hanger body, and can also be used for single-trip operations. The hanger holddown is released to retrieve the casing hanger once the sealing element has been retrieved. Ie,'12,>f. 8. ,,tsu,yu＊＃
f)! It can be used at 7'□6°, and when sending a hanger, it is possible to send an Oka hanger with or without a halt down. The sealing mechanism functions even if the holddown is not used. When running, the hanger hold down can be reused, and when it is placed between each umbrella hold down groove, the difference in the distance between the two can be kept to a minimum.

The sealing mechanism invented by H. has an outer diameter of 469.9M1 (1
In addition to completely sealing the annular portion with an inner diameter of 431.8 mm (1 inch) and a diameter of 1 inch, the sealing mechanism is given a power efficiency of 1054 mm.
1054.71/d (15,000 ps
i) (Name l 1406.2#/d (20,000psi
)) gives an elastic pressure. 1054.74/d (1
A pressure of more than 5,000 p-1) remains. The s/-le mechanism also provides an additional function of self-energy source to maintain the full pressure if the negative force is not fully applied or if the load force is not fully maintained. has been done. The seal mechanism is not designed to release energy when pressure is applied. The sealing mechanism is capable of sealing over a relatively long area, thereby eliminating housing defects and debris. In addition, the sheath/@ structure provides a primary) IN pair) Ik sealing action, and also prevents the secondary Efstomeric V-le from being pushed out under high pressure. The sealing mechanism of the present invention, used as a back-up, can be reliably removed when the metal-to-metal seal is removed from the wall prior to retrieving the core mechanism. The elastomeric seal of the sealing mechanism is a fully retrievable structure that allows for one inactive operation when the pack-off assembly is retracted. Also,
The Oka seal mechanism provides a secure metallic link between the top and bottom of the backing seal so that the bottom ring is retrievable. It is also designed to be suitable for single-trip operations. Since there are no intermediate metal parts in the V-ru region, uneven elastic pressure does not occur.

Since the area to be sealed by the sealing machine 5tFi is kept to a minimum, the leakage path is also kept to a minimum. ! The /-ru mechanism is integrated into the backing element! O″t, which is attached to
”, #Function will not be impaired by water flow throughout the prefecture.
It is designed to be used in multi-trip fw industry, and is compatible with all O casing hangers within the nominal size range.

Mechanism loading the sealing mechanism, call 14 to the sealing mechanism
The power to impart energy in the event of a pressure of 06.24/d (20,000p field 1) is ensured by K11l.

Therefore, if you use it for sale, you will not be able to sell it.
is possible. However, the loading mechanism can be used in single-trip operations and multi-trip operations. Additionally, all casing hangers within the well headrest stem are compatible. The loading mechanism allows the router to move when the casing hanger is set in the high position.

Nine, #l! The 1c1-ding mechanism does not release any of the total pressure after one operation. The loading mechanism does not need to be remotely engaged with the hold-down threads; the a-loading mechanism is reusable, and there is no need to remotely engage the hold-down threads with the backing nut replacement.

This casing hanger has a connecting part between the feed tool and the casing hanger, which is 317520#.
(700,000 bonds) or more. The feed tool can exert over 900,000 pounds of axial force to energize the V-ring mechanism.

In addition, the same feed tool can be connected to the casing hanger without left-hand torque. Furthermore, the same tool can be used for either the casing or the side valve pipe.

Other objects and advantages of the invention will become apparent from the following description.

・J's invention is a subsea well head 1iIW1 which is particularly useful for submarine wells having an operating pressure of about 1054.7 psi (15,000 psi), and this well head device generally consists of a well head, a casing, and a pressure load. a housing seat for supporting the casing, a casing hanger for suspending the casing in the wellbore, a casing hanger for supporting the casing, a well head Kll, and an annular portion formed between the casing hanger and the well head. A pressure sealing mechanism for the press sealing mechanism, a threading tool that first activates the press sealing mechanism when the casing hanger is lowered into the well head, and a pressure sealing mechanism that applies hydraulic pressure to the press sealing mechanism to perform compression at a pressure higher than the operating pressure of the wellbore, etc. It has related mechanisms. The well head receives other cage hangers arranged above and below in a row to hold and seal these casing hangers within the well head.

The hole diameter of the well head is standard 444.51 (171/
4 to allow the passage of 2 inches)
4418 (17'/14 inches) K is set. Mounted and connected to the well head are eight V-shaped seats that provide a support surface for supporting the casing hanger and pressure loads. The well head and housing seat are provided with closing teeth.
These O-connections are possible by rotating by 60 degrees or less. The closure teeth are constituted by six grooves having six teeth each, which are spaced apart and form a tube without a tube. The support surface for the closed teeth is provided for the support surface of the cage, and the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface for the support surface of the support surface for the support surface for the support surface of the support surface for the support surface of the support surface for the support surface of the support surface for the support for the support surface of the support for the support surface of the support surface for the support surface of the tooth for the support surface of the support surface of the tooth for the bottom of the end of the end of the end of the end of the end of the month for the end of the end of the end of the month as the end of the first year as well as for the end of the day, for the first time,” and so on, is also set wide. The support surface of the housing seat is 10
547#/d (1 rod QQQpsi) In addition to the 0 working pressure, it becomes the core that supports the casing and Chebinda OII weight.

The casing hanger includes an annular O-shoulder having a passageway for the passage of underground fluids. A safety ring is removably screwed onto the shoulder, and is engaged with a metal scrap at a 560° angle to support the weight and pressure load of the casing and the cylinder. A circle 1iI5 is formed on the well head.
ii! A #llK latch member is provided above the shoulder.

Casing hanger 0Ili! l and latch member and case V
A pressure sealing mechanism is provided above the shoulder O of the handle 10. The pressure sealing mechanism includes an electromagnetic rotating member rotatably supported relative to the unique member. The constant member has an upper actuating portion rotatable relative to the rotating member, an intermediate V-ru portion having a first rounded V-ru and a second elastic V-ru that V-ru the annular portion; and a lower force for moving the latch member.

The opening seal part is made up of a plurality of fustoconicas that are connected together by a connecting φ connector to form a voluminous shape.

It has a metal-like structure in the shape of oonl・al). This engraved shape is further connected to the upper lI actuating part and the lower l1iI five parts through a connecting point to form these 0IIK positive-acting linkers. Adjacent) Matching metal all? A rounded ring #l is formed in the rod to accommodate the elastic member.

The fixing member is screwed into the casing hanger, and the 7-rotating member is lowered and the 11111 fixed member is screwed into the casing hanger in a 9-in position. Shitaku is threatening. Then, first, the lower part of the latch member engages with the latch member and is fitted into the Ii1 electric groove of the middle L head, and the casing hanger is fixed within the well head. When the rotating member is further rotated, the inside of the fixed member @V
- #ll is compressed.

First, the li-shaped portion deforms and the metal link compresses the elastic member to engage the middle L head and the casing hanger. When the two shaped parts are further compressed, the metal link causes the adjacent connecting link to undergo shoulder self-deformation, forming a Merle evening mail V-~ between the casing hanger and the well head. The metal link is made of a ductile metal material having a sieving value of less than half of the material constituting the head and the casing hanger. It is possible to bite into the superior ON convex part.

I missed the ninth step when lowering the casing hanger and installing it.
The OX cart part and the drill pin are used to transmit the rotor (by engaging the pressing member of the structure O). >)
9> rKII So, wow! >fk#J-, jL cart club! When the mandrel is placed in the mandrel and placed in the O-ring, it has a latch that is engaged with the solder on the mandrel A/N. (lowers, then rises to engage the thread 1 with the skirt, and release the engagement of the casing hanger of the latch from the K). -k is provided.

The pressure sealing mechanism is rotated 9 times through the 9kl pipe.The INK is activated, and the blowout prevention mechanism is activated by rotating the drill pipe KM.
A V-rule (operated) is passed below the extrusion prevention mechanism and hydraulic pressure is applied to the pressure sealing mechanism. As the #8E11 paired mechanism O-seal m is further compressed, the At 9, torque is continuously applied to the pipe, and the rotating member also descends to a lower position. When the desired pressure is applied to the 5torr part, the hydraulic pressure is released. Then, the rotating member is pressed
Prevents loosening of V-rule engagement. The purpose is the working pressure of the well.] The sealing mechanism's V-
This is to be added to the Le section.

After removing the through stem, attach the 12 casing hangers that support the casing to the top of the 10th casing hanger.
Can be attached. A press-sealing mechanism operated like a press is provided at the well head and the 20th case V hanger and 0111, and the 20th case V hanger is press-sealed. In addition, a 30-year-old card was passed through Kuii, and the 20th
The cable is attached to the top of the hanger and is press-sealed by various press-sealing mechanisms. Thus, the henge seat supports the five O casing henges and the hanging pipe, and at the same time
1054.7 It will withstand and maintain zero operating pressure.

Next, one embodiment of this invention will be described with reference to the drawings.

The IML is a well head K installed in an offshore submarine well.
This diagram schematically shows a typical sink hanger and casing equipment, and in the figure, a wellbore 1° is formed in the ocean 12 below the ocean 14 by the MS ship 16 floating on the ocean surface 18. Basic structure: Guide pace 2G, conductor casing! ! 2. Equipped with a well head 24 and a pressure adjustment mechanism, the injection molding pressure stack 26 and! Lin riser 28 has been unloaded from IIN ship 16 and is attached to hawk 12. The conductor casing 22 is driven until the well head 24 stops near the ocean 12 .
1, or inserted into a drilled hole 30 as shown in FIG.

The guide base 20 is fixed to the upper end of the conductor casing 22 on the seabed 12, and is fixed inside the hole 30 by a cement hole 32 along the entire length of the conductor casing 28.

The blowout prevention stack 2- is connected to the seabed 12 via appropriate connectors.
It has one or more sand blowout prevention mechanisms, such as a sand blowout prevention mechanism 40, which is provided on the guide pace 20 attached to the sand and is detachably connected to the nine-well head 24. Such a blowout prevention mechanism, for example, the pipe twig 34 of the blowout prevention mechanism 40, is moved in and out of the blowout prevention mechanism housing, and sealingly engages a tubular member such as a well-known drill pipe for centrally exiting the blowout prevention mechanism 40. and has multiple sealed pipe rams to release.

The marine live 28 is ejected from the top of the blowout prevention stack 26 to the drilling ship 16.

The blowout prevention stack 26 includes a choke line 36 and a choke line 36 that extend to the sea surface 18, respectively.
) It has a conduit 3B. The fill line 36 and the kill line 38 are used for testing the pipe ram 34 of the blowout prevention mechanism 40, among other uses. During Test 1# of Pipe Tsum 34, inside the well! A test plug is retracted through the phosphor riser 28 and the wellbore is sealed at the wellhead 24 location. Vipram 34 is activated and closed, and then the kill pipe 3 is connected to the valve of the chiseled pipe 36 in the closed state.
Pressure is applied through 8, and the pipe stub 34 is tested.

A drilling rig with a drill pipe equipped with a standard 17"/lt inch drill bit is lowered through the marine riser 28 and conductor casing 22 to form a deep hole 42 in the seabed for the outer casing 44. In Figure 2c, the casing hanger 50 suspending and supporting the outer casing 44 is locked after lowering through the conductor casing 22 and is connected to the well head 24, which will be described in detail below.Other inner casings The Chibatake-Binda strings are also still locked and suspended from the well head 24 in the same manner as described below with respect to FIGS. 5A, 5B and 5C.

112c@, the well head 24 has a lower end s48
The wellhead housing 46 has a small diameter and defines a conical shoulder 52 that slopes downwardly and inwardly. The small diameter lower end 48 has a small diameter tubular s54 at its end and further forms a conical shoulder 56 that slopes downwardly and inwardly. Conductor casing 22
is formed from a pipe having an outside diameter of 508 mm (20 inches) and is welded to a small diameter tubular section 54 at the lower end of the well head 24. The thickness of the conductor casing 22 is 12.
7 holes (171 inches), the drill string and bit for drilling the deep hole 42 are first inserted, and then the outer casing 44 is inserted as shown in FIG.

The well head housing 46 is connected to the conductor casing 2
Slightly smaller diameter than the internal hole 62 of No. 2, approximately 4747cm (1B
It has a hole 60 having a diameter of "/ls inch).

Inside the hole 60 are a plurality of locking notches 64 and closing teeth 66.
And, 600 revolutions 1 above this closing tooth 6C! IK
There are four annular grooves, such as #I68, spaced apart. Closure-66 is approximately 4747-
(1g" 71@inch) deep hole with inner diameter 4
A standard 4445 mm (17"/s inch) drill bit for drilling 2 holes can be passed through.

Well head 24 removably includes a casing hanger support seat member or closure housing seat 70 that is lowered into large 60 and engages closure tooth 66 . The closure housing seat 70 has a cylindrical ring 72 defining a smooth bore 74 therein, an outwardly directed closure tooth 76 that engages the closure tooth 66 of the wellhead housing 46, and an outer casing hanger 5.
0 and a rounded keying mechanism 78 that secures the closure housing seat 70 within the well head housing 46.

The inner diameter of the ring 720 hole 74 is 4079cm (16°060
s1 sand at a conical support shoulder SSO at approximately 33° O (approximately 1.5 in.), sufficient to support the casing hanger 50.
3 inches) horizontal thickness. The wall thickness of the closing housing dust 70 is 413 for the closing housing dust 70.
27. Even if a vertical pressure of il-/d (90,000 pal) is applied, no crushing will occur. This relates to the fact that the bell head 24 is a rigid member compared to the closure housing seat 70, which is a relatively flexible member.

In FIG. 3, the closing nose seat 70 has a closing tooth 76.
A plurality of grooves 8z, which are segments of the grooves 8z, and corresponding grooves 88, which are formed between these grooves and are segments of the closing teeth 66 of the well head 46 shown in FIG.
The receiver has a closed groove for putting it in, i.e. between! It has a total of $86. The closing teeth 66 and 76 may have leads or may not have leads, but it is preferable that they do not have leads. In this example,
The closure teeth 66 and 76 are designed to interfere with each other and not engage with each other when the closure nousing dust 70 is rotated and connected to the well head 24.
The closing tooth 66 on the fourth side is sloped inwardly and downwardly, making it easy for the bit to pass through. 4H If the closing teeth 66 are in the shape of a square step, that is, if they are of the serrated type, then when trying to lower the rounding bit that opens the large hole 42 for the outer casing 44 through the well head 24, the bit will You'll probably get caught. Closing tooth 76 has a corresponding nine bevel to just mesh with closing tooth 66 of well head 24 . grooving 82
．． 88 each has a height of approximately 12.7 from the root of the tooth to the tip of the painting.
wm (''/s inch). The area of the six rows of teeth of the closing teeth 66, 76 is larger than the area of the support shoulder 80. Above the closing teeth flow. The upper annular 7 flange 85 connected to the closed @/S waging seat limits the degree of insertion into the groove 820. The segment 84 provided at the bottom is closed/S when the well head By being rotated by -1-> within 24, F
A margin is provided to prevent the IR-shaped flange portion 85 from being hit.

The six rows of grooves 82.88 of the closure teeth 66.76 support and distribute loads in equal numbers, and such an arrangement averages out the stresses on the closure teeth 66.78. In addition, by providing 6@ grooves on each closing tooth, the closing@66 and closing tooth 76 are closed) and the mounting seat 70 can be rotated by 9 degrees, that is, 30 degrees divided by 1806 by the number of grooves. It can be made to mesh well.

The longer the length of the closure *66.76, the greater the angle of rotation of the closure housing seat 700 required for engagement. It is desirable that the closing teeth 66, 76 have equal lengths so that they can support the load with maximum contact.

The closing tooth 66.76 is simply a groove or gap between 1986°87
In this case, the closing tooth 66.76 may be connected with a circular groove having a lead angle -I! It is #4 and has a taper to increase the engagement area and be able to withstand large shear stress. In addition, the closing tooth 6
The 6.76 taper is preferably greater than 30@, about 55@, so that the combined area is substantially increased to withstand shear. Such a tooth profile equalizes the stress on all of the closing teeth 66, 76 so that the ninth WA chain tooth 66, 76 does not yield all at once.

The closing teeth 66.76 may also be of the sawtooth type, but in this case the rectangular steps of the closing teeth 66.76 will trap rock debris and other debris from the wellbore. The method of closed coupling between the well head 24 and the closure housing seat 70 has the further advantage that the closure teeth 76 serve to clean the closure 68 when the closure housing seat 70 is rotated within the well head 24. . Closing tooth 76 is closing tooth 66
It scrapes out any debris and drops it into the closed ditch, or Seki@86.87.

The continuous thread type has several disadvantages.

For example, a screw must be rotated many times between connecting rounds, and must be backed up until the screw leads reach a 1 inch Sm before they begin to engage.

9. With screws, when rotating for connection, they are supported at a point.

By providing a closed connection between the closure housing seat 70 and the wellhead 24, these drawbacks are eliminated, and the lowermost segment 84 of the housing seat 70 is connected to the closure tooth 6 of the wellhead 24.
6 top seven Gumen) K hit. In that case, by rotating the closed housing seat 70 by 30 degrees or less, the grooves 82 of the closed housing seat 70 can be inserted into the grooves 87 between the grooves 88 of the well head 24. The lowering distance in this case is approximately 304.8 inches (12 inches) so that the closed housing seat 70
4 can be easily detected from the outside, and the connection is closed by rotation. The closure connection of the present invention provides a clear indication when the closure housing seat 70 is fully coupled to the wellhead 24. The closed connection of the present invention has the additional advantage that a complete connection between the closed housing seat 70 and the well head 24 can be achieved by inserting the closed housing seat 70 into the well head and rotating it 30''. It will be done.

20, 3 and 3A, the key mechanisms 781 are each slidably inserted into an outwardly opening recessed groove 94 provided in every other lowermost segment 84 of the ring 72 and attached outwardly. It has a plurality of dogs 92 that are energized.

The dog 92 has a plane 9o and an upwardly and downwardly inclined surface 91.
and a groove 96 formed inside to receive one end of the spring 98.

The washer part 93 is attached to the dog 9 while leaving a groove for the dog 92.
2 is mounted in the circuit 94 on both sides. The other end of the spring 98 is locked to the bottom of the groove 94 and the dog 92
is biased outward. The locking notch 64 is provided directly below all six glue pins 88, and the locking notch 64 is provided directly below the glue pin 88.
2 to the ring 72 and attach the well head housing 4.
When engaged with the notch 64 of the well head 24), the closing tooth 66 on the inside of the well head 24 and the closing tooth 7 on the outside of the closing housing seat 7o
It is possible to achieve complete meshing with 6. When the ring 72 is rotated inside the closure tooth 66, the dog 92 will close the notch 6.
4, the rotation of the ring 72 is stopped. dog 9
2, a hole 102 is provided through the ring 72 and communicating with the recess #94.

In prior devices, the support shoulder of the casing hanger was integrally formed with the well head housing and had sufficient length to support the casing and pressure loads. However, conventional integral support shoulders have limited the hole in the well head housing to a hole large enough to receive the casing below the well head for drilling.

When utilizing a solid shoulder large enough to withstand an operating pressure of 1054.7 KI/cd (15,0009 at), the standard 444.5 KI/cd (171/!) hole in the solid shoulder is used.
inch) drill bit does not go through. Such well head systems require drilling at the bottom.

In this embodiment, the closure housing seat 70 is a removable support shoulder that does not need to be attached to the wellhead housing 46 unless significant operating pressure is applied. The closure housing seat 70 is not installed until the drilling for the outer casing 44 is completed, thus allowing for a sufficiently large hole to be provided. Il of drilling holes in the outer casing 44;
No large support shoulders are required since the is only subjected to normal operating pressures. After the drilling for the outer casing 44 is completed, the closing housing seat 7o is installed to carry the casing and pressure loads of 9/J 15,000 pal ) K at 1054.7. In this way, before the closing housing seat 7o is installed, the distance is 444.5 m (1
Sufficient clearance is provided for a 71/, inch) drill bit to pass through.

When the closed housing seat 70 is attached, a portion of the closed housing seat 70 is removed by a Surebin (not shown).
It is connected to the threading tool shown in 4.

The drill string threader is then lowered into the bore 60 of the wellhead 24 until the lowermost segment 84 of the closure housing seat 70a rests against the uppermost segment (K) of the closure tooth 66. Closure housing seat 70 is then rotated until groove 88 of well head 24 falls into recess 986 and groove 82 of ring 72 enters corresponding recess 987 of closure tooth 66 of well head 24. Then, the annular 7 flange portion 85 engages the closing teeth 66 of the well head 24.
rests on the top segment of Thereafter, the closing housing seat 70 is rotated until the key mechanism 7-8 is locked in the locking notch 64 and rotation is stopped, and the closing housing seat 70 is
A pressure test can be performed to ensure that zero is depressed. Additionally, the surebin holding the closure housing seat 70 to the threader is sheared off at part 104, and the threader is removed.

FIG. 2C shows the casing hanger 50 supported in the well head 24 by the closed nousing seat 70, with the casing hanger 50 being positioned in the deep hole 42 at the ninth point from which the outer casing 44 is suspended. 44
A substantially cylindrical main body 110 having a lower threaded portion 112 screwed into the upper portion of the main body 110 and an upper thick walled portion 114 having an annular shoulder portion 116 projecting outward, which will be described in detail below. The main body 110 has a plurality of annular #1120 (see FIG. 2B) formed on the inner periphery of the main body 110 to be connected to the threading tool 200.

2A and 2B, a threaded portion 118 is formed on the outside of the cylindrical main body 110 along almost its entire length, and is threaded into a suppression sealing mechanism 180, which will be described later.

The outer casing 44 and the conductor casing 220 are used for filling the outer casing 44 into the deep hole 42 with cement.
It is necessary to form a passageway from the lower annulus 130 between the holes to the upper annulus 134 at the junction of the wellhead 24 and drill string 236 to direct the return to the surface. Upper thick part 1
14 includes a plurality of upper and lower grooves or circulation bows).
122, 124 are formed to allow fluid to flow around the casing hanger 50, for example for cementing operations. Lower part $122 is shoulder part 11
6, and the upper groove 124 provides a passage through the cylindrical body 11.
0 provides a passageway through the top threaded end of the retainer 180 to allow fluid to pass around the retaining seal mechanism 180.

A threaded portion 126 is formed on the outside of the upper thick interior 114 below the shoulder portion 116 to receive and screw into the six shoulder rings 1z8 around the casing hanger 50. The shoulder ring 128 has a conical surface 132 sloping inwardly and downwardly to close the closure housing seat 7.
It abuts and engages with a conical support shoulder 80 that is inclined outwardly and upwardly. The casing hanger 50 is thus attached to the closure housing seat 70 by engagement of the conical surface 132 of the shoulder ring 128 and the support shoulder 80, so that it does not withstand the resulting casing and pressure loads. Must not be.

In wells with operating pressures on the order of 1054.7'/d (15,000 Pat), unique loads are placed on the well head support. Not only must the well head support the weight of the casing suspended thereon with the casing hanger, and the weight of the one or more cheeping hangers from which the cheeping is suspended, but the
It must withstand an operating internal pressure of as much as t, zd (15, Oo op severe 1). Like this K.

The wellhead must support the weight of the casing and chipping as well as the pressure loads.

1o54. When designing a well head that is subject to operating pressures of rh, -(ts, ooop Hatake1), the support and bearing parts must be sufficiently strong so that the load does not exceed the yield stress associated with vertical compression of the well head support member. It must be ensured that the For low operating pressure, 492 trKq e (oo to 7).

Although materials with yield values below 1054.7 Kf/, 7 (15,000 pal) are used
For O-well heads, typically 5976.4'f/, 1(8
A material having a yield value below 5,000 psi) is used. Well yYK is conservatively 6327.9'f
Assuming that a -direct compressive stress of /d (90,000 p@1) is applied, the area of the support part of the well head of the example is 419 d to 452 d (651 nch" to 701 nch").
nch”) in the range of Lenote, 271,600Kg
(6,000,000 lbm) or more. Such supports must be designed tail-through so that the load does not exceed 25* of the yield value for vertical compression of the material. Lowermost casing hanger 5
0 and the closure housing seat 70 and between the closure housing seat 70 and the closure *66 of the well head 24 such that such loads do not substantially exceed the yield value for vertical compression of the material. That is, it must be sufficient to support the yield value not exceeding 25-
The well head of this embodiment has such a design.

In order to provide a sufficient support area between the casing hanger 50 and the closing housing seat 70, the shoulder ring 128 is screwed onto a shoulder 116 projecting from the upper thickened portion 114 of the main body 110. Shoulder ring 128 is closed housing seat 70
360' conical surface 13 for locking the support shoulder 80 of the
2, thereby providing complete surface contact between the support shoulder 80 and the conical surface 132. Without the shoulder ring 128, the groove or circulation portion 122 in the shoulder 166 would
The 360° support between the casing hanger 50 and the closed housing seat 70 is lost.

The engagement of the support shoulder 80 with the conical surface 132 results in a 446.09 (17"/1s inch) inside diameter of the well head and a 407.921" inside diameter of the closure housing seat 70.
″(°・060(/?) “°1 constant” 5bh, btii
A support area larger than , * can be obtained. Thus, the area of the support between the support shoulder 80 and the conical surface 132 is approximately 45
2 cd (701 nch”), and with such a support, 271,600 Kg (6,000,0001 bm
) can support loads greater than

Inner and outer closing teeth 66°76 of well head 24
The closed housing seat 70 also provides sufficient support to support the anticipated loads as described above. As already mentioned, the closure-66, 76U wellheads 24 and closure housing seats are each provided with six groupings 82,88. Each grouping 82,88 has 6 teeth 1 for supporting loads. The support area of the closures 66, 76 is greater than that between the support shoulder 80 and the conical direction 132. The number of teeth is 1!18 at 6 points that accept the corresponding grouping 82.88 during assembly.
It is determined in consideration of the reduction in support area according to 6.87.

Now, returning to FIG. 2C again, the shoulder portion 118 protruding from the upper thick walled portion ILJ of the main body 110 has a conical cam surface 136 that is inclined inwardly and upwardly.
6 has an annular groove 138 extending upwardly from its proximal end. Annular vertical sealing surface 1 from the top of annular #138
An annular chamber 142 extends from the annular # 1138 to the lower end of the threaded portion 118 . Shoulder 116 is installed after casing hanger 50 is installed within well head 24.
It is located below the annular body 68 of the well head housing 46. Camming surface 136 has a lower annular end extending just above the lower end of groove 68 .

Casing hanger 50 has a latch ring 144 attached to shoulder 116. The latch ring 144 may be a split ring that is expanded within the groove 68 and latched to the well head housing 46 to hold and secure the casing hanger 50 within the well head 24 . The groove 68 is connected to the vertical wall 146 which is the base of the up-sloping wall and the down-sloping wall.
have. Latch ring 144 has a vertical surface 148 at the base of a downwardly sloped surface of the same length as the upwardly sloped wall of groove 68 and an upwardly sloped surface parallel to the downwardly sloped wall of 1168 9 so that latch ring 144 expands. Then, the vertical l1148 of the latch ring 144 hits the vertical wall 146 of the groove 68. The latch ring 144 further includes a lower cam surface 152 that is inclined outwardly and downwardly and that is cam-locked to the upward cam surface 136 of the shoulder portion 116, and an annular projection 154 that is inwardly protruding and fits into the inner part of the annular groove 138. and, as detailed below,
It has an upwardly inclined cam head 156 that engages with the suppression sealing mechanism 180 in a cam-like manner.

When the annular protrusion 154 protrudes into the groove 138 of the casing hanger 5o, the latch ring is prevented from coming off from the groove 138 when the casing hanger 5o is passed through the wellbore. In the process of attaching the casing hanger 5o, the latch ring 14
4 must pass through a number of small diameter sections, for example in the blowout prevention mechanism. The anti-blowout mechanism 40 often has a donut-shaped rubber seal that is not fully retracted, and therefore the casing hanger 50ri must be pushed through such a rubber seal. If the annular projection 154 did not protrude into the groove 138, the latch ring 144 would become caught in such a small diameter portion and be dragged along the outer surface. For this reason, the latch ring 144
is pulled out of the groove 138 and is now able to slide upwardly along the casing hanger 50 until it is locked into the sealing mechanism 210. This not only prevents the operation of the presser mechanism 212 but also the operation of the seal mechanisms 2 and 10. The annular chamber 142 provides a clearance for the annular groove 138 to receive the annular protrusion 154 .

Further, the shape has the role of preventing the latch ring 144 from being affected by a load when a load is applied to the latch ring 144 from above.

As shown in FIGS. 2B and 2C, the suppression sealing mechanism 1
80 has a pawl member 184 rotatably attached to a rotating member, that is, a packing nut 182 via a retainer 186.

Patsukin nut 182 has a pin 188 at the bottom of the door.
A ring-shaped main body and a locking part 202 that projects upward and downward.
It has a grooved upper end 198 with a grooved upper end 198. The body 11 of the casing hanger 50 is attached to the inner circumference of the packing nut 182.
Threaded part 2 that screws into threaded part 118 formed on the outside of 0
04 is formed.

The stop or claw member 184 has a ring-shaped main body 216, and a sealing mechanism 210 for sealing between the inner hole wall 61 of the well head 24 and the outer vertical sealing surface 140 of the casing hanger 50; The ring-shaped main body 216, which has a holding mechanism 212 for moving the latch ring 144 and fitting the #16gK of the well head 24, is made of a continuous and integral metal member.
B, a two-shaped portion 220 in the middle, and a cam portion 222 at the bottom.

The upper drive portion 218 has a retaining hole 190 at the top into which the lower pin 18B of the packing nut 182 is rotatably inserted. The retainer 186 has a retaining hole 190 and a pin 18
The inner and outer receivers 8 and 8 have grooves within which are provided sVc retainer rollers or balls 196. Retainer 186 does not support any loads, and packing nut 182 is not utilized to transmit torque or thrust to pawl member 184. Bearing mechanism 205
is provided above the sealing mechanism 210, and the retaining hole 1
Bearing rings 206 and 208 are interposed between the bottom of the pin 90 and the lower end of the pin 188. The bearing rings 206 and 208 have a small coefficient of friction, and the holding mechanism 2
12 and the seal mechanism 210 are slidable relative to each other.

Therefore, the bearing mechanism 205 is equipped with a packing nut 182.
It is used to transmit thrust from the stop pawl member 184 to the stop pawl member 184.

Ball 196 merely rotatably supports detent member 184 relative to the packing nut.

The holding member 212 is attached to the cam head 1 of the latch ring 144.
56 and an upper drive section 218 for transmitting thrust from the packing nut 182 to the lower cam section 222. 2-shaped portion 220
It has

The sealing mechanism 210 includes a two-shaped portion 220, an elastic member 3309332 forming an elastomeric backup seal, which will be described in detail below in connection with FIG. 4, and an upper drive portion 218 for pressing the middle two-shaped portion 220. It includes a lower cam portion 222. Seal mechanism 210 is a combination of a primary metal-to-metal seal and a secondary resilient seal. -The provision of a metal-to-metal seal has the advantage of not causing deterioration like a paper or elastic seal.

The containment seal mechanism 180 is lowered into the wellbore through the casing hanger 50 via the threader 200.

The threading tool 200 has a mandrel 230 serving as its main body, a connecting portion or sleeve 240, a skirt portion or outer sleeve 250, and a nut 260 for assembly.

The mandrel 230 has a pin end 232 at the top with an internal thread 234 for connection to the lower end of a drill string 236 extending above the sea surface 18 and a pin end 238 at the bottom, which also has an internal thread. That's it. box end 238
has a small diameter annular groove 242. Another small-diameter annular groove 248 is provided above the groove 242, and an annular protrusion 252 is formed therein. Below the upper pin end 232 and above the small diameter groove 248 is a threaded portion 254 (with a smaller diameter than the grooves 242, 248).
(see FIG. 2A) is provided.

#i field-like protrusion 252 on the connecting body or sleeve 240
Nine persons 246 are formed and dimensioned to movably surround box end 238. The annular protrusion 252 is the hole 2
O-ring 264, 2 for sealing with the inner surface of 46
66 are respectively installed in the annular seal grooves 258, 262.
have. The upper end of the sleeve 240 has an inward annular 7-flange portion 268 that slides into contact with the surface of the small-diameter annular groove portion 248.
is formed. A small diameter portion 270 is formed at the lower end of the sleeve 240 and is dimensioned to slide into the hole 272 of the casing hanger 50. This small diameter portion 270
forms a downward-facing annular shoulder 274 that is engaged with the upper hook 276 of the casing hanger 50 when the threading tool 200 and the pressure sealing mechanism 180 are attached to the casing hanger 50 in the well head 24. .The small diameter portion 270 is
A plurality of teeth 2 that fit into the annular groove 120 of the casing hanger 50 and connect the threading tool 200 and the casing hanger 50
A segment or dog 280 having a diameter of 82 is slidably inserted into a window or window 278 at circumferential intervals. The dog 280 is a protrusion 284 that is inserted into an annular groove 286 formed around the upper inner part of the window 278.
It has at the top. Above the window 278 are a plurality of seal grooves 288, 29 into which O-rings 292, 294 are installed for sealing between the hole 272 of the casing hanger 5G.
0 is set. A round snap ring groove 29 is provided near the upper end of the outer periphery of the sleeve 240, into which a snap ring 268 used for assembling a threading tool 200, which will be described later, is attached.
6 is formed. When the threader 200 is torqued to assemble the pressure seal mechanism 180, the dog 2
80 is pushed back into the groove 242.

The skirt or outer sleeve 250 has a generally cylindrical body with an upper inwardly directed radial section 300, an intermediate section 302, a transition section 304, and a lower actuating section 306. Each of these parts 300.302°304 and 306F
They are adjacent to each other and dimensioned to enclose the upper end 276 of the casing hanger 50, the sleeve 240, and the indrel 230. The lower actuating portion 306 has a grooved lower end 308 that engages with the grooved upper end 198 of the cap nut 182 so that the threaded stem 2
Torque can be transmitted from 00 to the press sealing mechanism 180. The inner diameter of the operating part 306 is the same as that of the casing hanger 50.
The size is set to be sufficient so that it does not interfere with the threaded portion 118 of.

The intermediate portion 302 slidably surrounds the sleeve 240 and presses the threading tool 200 to seal the sealing mechanism 180 as described below.
When removing the sleeve 2 from the casing hanger 5o,
It has an annular #1310 on the inside that receives the snap ring 298 provided at the end. Intermediate 5302 also has a strong threaded hole 312 formed from its outer periphery to annular 11310 so that snap ring 298 can be inserted into annular 11310 while resetting threader 200 to another casing hanger. This can be done by screwing a bolt (not shown) into the annular groove 310 to prevent it from coming off. Snap ring 298 has a cam surface 316 on the top against which the end of the bolt rests. Once sleeve 24G is in the upper annular portion formed by outer sleeve 250 and mandrels 30 and K, sleeve 240 cannot be removed without inserting snap ring 298 into annular groove 310. In this way, the threading tool 20
0) To remove the sleeve 240,
A bolt is screwed into the screw hole 312 to close the annular a310 so that the snap ring 298 does not enter the annular groove 310 and become locked. Thereby, the sleeve 240 is lowered along the indrel 230 until the shoulder 269 is locked by the annular protrusion 252 and is ready for connection with another casing hanger.

A transition section 304Fi is provided between the actuating section 306 and the intermediate section 302 to compensate for diameter changes and to allow cement to pass back through the outer sleeve 250 and into the upper annular section 134. A flow port 318 is provided.

The annular inner peripheral surface of the upper radial portion 300 is provided with a groove 9 to form a spline connection 320 with the mandrel 230 to enable torque transmission.

2A and 2B, the screw 23 of the small diameter threaded portion 254 of the mandrel 230 is attached to the inner periphery of the nut 260.
5 and a portion 322 are formed with a screw 324 that is threadedly engaged with the portion 322. When assembling, the lower end surface of the nut 260 is brought into contact with the upper end surface of the outer sleeve 250, and the outer sleeve 250 is attached to the mandrel 23.
It is fixed at 0.

When working, simply attach one bag of nuts 182 to the casing hanger 50
71 if partially screwed into the upper threaded part of
A mandrel 230 can be attached to the casing hanger 50 in a threaded position. In the passing position, the annular protrusion 25
2 is the shoulder Ifl! formed by the annular flange portion 268 of the sleeve 240. 269. The cylindrical surface of box end 238 abuts portion I1 within dog 2800, thereby forcing tooth 282 toward annulus 11120 of casing hanger 50 and attaching thread 200 and casing hanger 50 to the drill string. This prevents the separation of the seven rails when the shaft is lowered into the well. The threading position of JL2000 is not shown.

When the shoulder ring 128 of the casing hanger 50 rests on the support shoulder 80 of the closed housing seat 70 in the wellhead 24, the outer casing 44 is cemented with the internal potential of the deep hole 42. Threading tool 20 after cement filling work is completed
0 is rotated to transmit torque to the sealing mechanism 180, and the push sealing mechanism 180 is moved to the depressed position shown in FIGS. 2B and 2C. Rotating the drill string 236 at sea level 18 rotates the mandrel 230;
Furthermore, the outer sleeve 2
50 is rotated. The torque of the outer sleeve 250 is further applied to the locking portion 202 of the cap nut 182 and the outer sleeve 250.
It is transmitted to the packing nut 182 via the connection portion with the grooved lower end portion 308 of. An axial load is applied to the pressing sealing mechanism 18G by the cap nut 182, and the cam portion 222 of the pressing mechanism 212 moves to engage the cam head 156 of the latch ring 144. Such cam engagement causes latch ring 144 to expand toward groove 68 in well head 24, locking well head housing 46 and compressing casing hanger 50 within well head 24 as shown in FIG. Fix it. Here, the pressure sealing mechanism 180 has not yet exerted a sealing effect between the upper annular portion 134 and the lower annular portion 130. Only a predetermined cam load is required to actuate the latch ring 144 and therefore has a predetermined retraction tensile strength. The cross-sectional structure of the sealing mechanism 210 is similar to that of the pushing mechanism 2.
The design is such that actuation and camming of the latch ring 144 by 12 ensures that it will not compress prematurely. The load required to compress seal mechanism 210 is sufficiently greater than the load required to expand latch ring 144. Pressure sealing mechanism 180
When actuated, the mandrel 230 is lowered together with the outer sleeve 250, and this lowering of the mandrel 230 releases the dog 280.

Sealing mechanism 21 regarding the through and suppressed positions and the sealed position
See FIGS. 4 and 4A, respectively, for an explanation of 0° round. The sealing mechanism 210 has two metal parts 2.
20 and upper and lower elastic members 33 made of nidistomer material.
0.332, these two shapes 5220, and the resilient member 330,
It has an upper drive part 21B and a lower cam part 222 for compressing 332. The two-shaped portion 220 made of annular metal is connected to a plurality of annular links 334, 336, and 336 connected to each other by connection rings 340 and 342 also made of annular metal.
and 33B, the upper part of which is connected to the drive part 218 via a metal connection ring 344, and the lower part thereof to the cam part 222 via a metal connection ring 346.

Annular links 334, 336 and 338, along with connecting I-rings 340, 342, 344 and 346, provide a vertically positive connecting link between lower cam portion 22 and upper drive portion 218.

Such a positive connecting link allows the annular link 334
．． 336 and 338 are the seal mechanism 210 and the presser mechanism 2
12 moves back from the well head 24 into an uncoupled position and moves to a more inclined uncoupled position with respect to the well head 24 and casing hanger 50. Such a positive connection link also provides a metallic connection from the drive section 218 to the cam section 222, so that the cam section 22 is connected in the event of disengagement.
A positive upward load can be applied to 2.

Although it is not necessary for such a return 9, the connecting ring 34
0,342,344 and 346 may be omitted.

The length of the connecting rings 344 and 346 adjacent to the driving part 218 and the cam part 222 is equal to the annular link t7.
334, 338 must be minimal to ensure sealing engagement. Moshi connection ring 344.34
If 6 is too short, the annular link 33 will be insufficiently bent.
4.338 is inside -61, vertical sealing surface 14 respectively
Cannot touch 0. Since the drive portion 218 and the cam portion 222 are larger in size than the connecting rings 344 and 346,
These portions 218, 222 are solid and do not bend to #1 where the annular links 334, 338 can sealingly engage, so that the annular links 334, 338 are substantially unable to make such bends. Become. Connecting ring 34
0, 342, 344 and 346 are metal two-shaped parts 2
Provides localized high stress contacts throughout 20.

The metal bi-shaped portion 220 is made of highly flexible and ductile steel, such as 316 stainless steel. Such metals are approximately 2812” 4/4 (40,000p
si), and this value is equal to well head 2
4 and the yield value of the constituent material of the casing hanger 50 5
This is less than half of 976'9/d (85,000 psi). The two metal shapes 5220 are plastically deformed when they are in sealing engagement, but the internal hole l161 of the well head 24 and the vertical sealing surface 140 of the outer casing nozzle 50 tend to be elastically deformed.

Even if there is any defect in the inner hole wall 61 and the vertical sealing surface 140, the constituent metal of the two-shaped portion 220 will deform along the convex portion of the defect due to its ductility or enter the concave portion, so that high pressure metal-to-metal You will get a sticker. In this way, the metal two-shaped portion 220 engages the internal hole wall 61 and the vertical sealing surface 140, respectively, to make sealing contact.

The upper, middle and lower annular links 334, 336 and 338 each have a diamond-shaped cross-sectional shape.

These annular links 334, 336, and 338 have substantially the same cross-sectional shape, so only the annular link 336 will be described below, and the explanation of the annular links 334 and 338 will be omitted. The annular link 336 has a generally parallel upper annular surface 348 and a lower annular surface 350, and the upper annular surface 348 and the lower annular surface 350 have an upwardly directed outer annular surface 352 and a downwardly directed inner annular surface that are substantially parallel to each other. 354 respectively, and radially outward of the outer annular surface 352 and radially inward of the inner annular surface 354 are formed an outer annular seal contact rim 358 and an inner annular seal contact rim 356, respectively, which are generally parallel to each other. There is.

The annular links 334, 338 have similar corresponding tops.

It has a lower annular surface, outer and inner annular surfaces, and an outer and inner annular seal contact rim.

In the suppressed position, the annular links 334, 336 and 3
The seal contact rim 38 connects the internal inner wall 61 of the wellhead housing 46 and the vertical sealing surface 1 of the casing hanger 50.
It deforms almost parallel to 40. Upper connecting ring 344
extends from the lower end 364 of the upper drive portion 218 to the upper annular link 334 to form an annular channel 366 .

The metal connecting ring 340 extends from the lower surface 337 of the upper annular link 334 to the upper annular surface 3 of the intermediate annular link 336.
48 to form an annular channel 368, and a metal connecting ring 342 connects the intermediate annular link 33.
6 extends from the lower annular surface 350 of the lower annular link 338 to the upper surface 339 of the lower annular link 338 to form an annular channel 370. The lower connecting ring 346 is connected to the lower annular link 3
From the lower surface 341 of 38 to the upper end 372 of the lower cam portion 222
and extends to form an annular channel 374.

These channels between adjacent protrusions 366°368.3
70 and 374 assist in bending the bi-shaped portion 220 at predetermined locations, namely the connecting rings 340, 342, 344 and 346 positions. The lower end 364 of the drive portion 218 is substantially parallel to the upper surface 335 of the upper annular link 334, and the upper end 372 of the cam portion 222 is substantially parallel to the lower surface 341 of the lower annular link 338. In the through and suppressed positions, the outer and inner seal contact rims are connected to the upper drive part 218 and the lower cam part 2.
It has a diameter similar to the inner and outer diameters of each of 22.

The upper and lower elastic members 330.332 are molded in the same shape as the annular grooves 376.378 formed by the annular links 334.336 and 338, and are bonded to the annular links 334, 336.338. There is. Upper and lower elastic members 330゜1 33゜Y7-2□1
Hey rnslii61.

It has an outer annular vertical sealing surface 380 and an inner annular vertical sealing surface 382 for coming into close contact with the vertical sealing surface 140, respectively. Outer and inner annular vertical sealing surfaces 380
, 382 are shaped to deform during compression to bring the elastic members 330, 332 into a sealing position. The elastic members 330, 332 are also shaped to allow a predetermined deformation between the annular links 334, 336, 338. Although the cross-sectional shapes of the elastic members 330 and 332 are substantially the same, the inner elastic member 332 can provide a non-protruding seal from the outer elastic member 330 to the wall 61 and the vertical sealing surface 140 of the casing hanger 50.

Preferably, the sealing mechanism 210 has at least three links, such a number providing a non-protruding link on each side of the resilient member 330,332. Also, three annular links 334.33
6 and 338 can be of symmetrical design. However, the sealing mechanism 210 may have one or more links, and may have a series of links holding multiple resilient members.

The lower end 364 and upper end 372 of the drive portion 218 and the lower cam portion 222 each preferably taper in the same direction as an adjacent link, such as the annular links 334, 338 shown in the above embodiment.

By forming the annular links 334, 336, 338 into a rhombic cross-section, their central portions are very strong. The reduced cross-sectional area at the end of the annular link 334, 336° 338 is connected to the connecting ring 340° 342, 344, 3
It becomes a bent part like the part near 66. It is undesirable for the annular links 334, 336, 338 to bend in the middle. However, the reason why the cross-sectional shape is particularly diamond-shaped as shown is simply because it is easy to process into such a shape. The annular links 334, 336, 338 may be formed in a continuous eastern or elliptical shape.

Such a shape is frustoinodic.
oconoidie), and a protrusion is formed in the center. If the cross-sections of the annular links 334, 336, 338 were of the same thickness, they would tend to bend in their midsections. The annular links 334, 336, 338 are used to control the bending point at the rim position to ensure a predetermined plastic deformation and to ensure that deformation in the center of the annular links 334, 336° 338 is eliminated.
It is preferable that the central part of the annular link 3 is thick.
34°336.338 is a frustoconical ring with a slightly more uniform cross-sectional thickness than a frustoconodic ring.
(toconical) metal ring and may be 4.

4 and M4A, the sealing mechanism 210 is in the sealing position in FIG. 4A, and when the presser mechanism 212 reaches its limit of movement relative to the latch ring 144 and the packing nut 182 continues its downward movement by the threaded portion 118 of the casing hanger 50. Seal mechanism 210 is compressed.

The metal-to-metal seal mechanism 210 is moved sequentially from the bottom to the top. In other words, the lowermost annular link 338 bends while compressing the sealing mechanism 210 and first begins to come into sealing contact with the internal bore wall 6.1 and the vertical sealing surface 140. Such a sequence of movements will cause the upper annular link 334, 336 to contact the seal m before the lower annular link 338.
336 is preferred because it prevents it from dragging down the internal hole wall 61 and vertical sealing surface 140. Also - it is preferred that the forces applied to the upper annular link 334 be balanced.

Resilient members 330, 332 provide an initial seal. The elastic members 330, 332 are annular links 334°336.33
8 contacts internal hole wall 61 and vertical sealing surface 140 before rim 8. For example, if the sealing mechanism 210 has a slight
When an initial compression of about 11 Kf/, -j (3,000 psi) is applied, the elastic member 330°11°32
0') 1”tm, tl*m1iB?knee blzv・1
The shaped links 334, 336, 338 are elastic members 330°3
32 and a holding mechanism for the elastic member 330. In this way, the rims of the annular links 334, 336, 338
32 protrudes beyond the adjacent rim before the internal bore wall 6
1 and vertical sealing surface 140 is desirable. The interposition of elastic members between the rim and the internal hole 61 and the vertical sealing surface 140 also includes annular links 334, 336.
It is undesirable for such protrusion beyond the rim to occur prior to sealing contact of the rim, as this would adversely affect the sealing engagement of the rim. As explained above, the volume of the elastomeric material constituting the elastic members 330, 332 is such that the rim is formed between the inner hole wall 60 and the vertical sealing surface 1 prior to any protrusion of the elastic members 330, 332.
41 by calculation in advance.

The annular links 334, 336, 338 are 141 to 21
til+/, 4(2o o o ~a o o o o p
at) o Designed to be thin enough to deform and seal into sealing engagement under slight compressive forces. Connection ring 340.
342 and 346 form stress concentration points or weak points in the annular two-shaped portion 220 to allow the two-shaped portion 220 to bend at predetermined positions. Wall 61 and vertical sealing surface 140
Proper sealing engagement.

When the actuation is completed, the rim bites into the internal hole wall 61 and the vertical sealing surface 140, and the rim engages the internal hole wall 61 and the vertical sealing surface 140.
A metal-to-metal seal may be formed at K to seal the upper annular portion 134 from the lower annular portion. The sealing mechanism 210 is designed to ensure that no flow or leakage path formation occurs between the internal bore wall 61 and the vertical sealing surface 140.

In the sealing position, the lower annular link 338 flexes at the connecting ring 346 and the outer surface 343 of the lower annular link 338 moves downward to engage the upper end 3 of the lower cam portion 222.
72 is locked. The upper end 372 of the cam portion 222 is sloped to provide an initial displacement angle for the lower annular link 338. Additionally, the upper end 372 ensures that the annular link 338 is never horizontal and that the sealing mechanism 210
It is possible to prevent the annular link 338 from becoming uncoupled when the annular link 338 is removed. When the lower end 364 of the drive unit 218 moves downward, the upper annular link 334 bends at the connection ring 344, and the inner rM333 of the upper annular link 334 bends at the lower end 364.
2> Push the EZ shape part 220 and lock the lower end 364 at the same time. Elastic member 330°332tj annular link 334
, 336, 338 and tightly contacts the internal hole wall 61 and the vertical sealing surface 140. Annular links 334, 33
6,338 inner rim is outer casing hanger 5o k
f [Points 380, 382, 38 for seal I1140
3, and the outer rims of the annular links 334, 336, 338 make annular sealing contact with the interior bore wall 61 of the well head 24 at points 386, 388, and 390. The seal mechanism 210 is thus capable of making annular metal-to-metal seal contact at six locations. Due to the sealing contact between the inner and outer rims, the annular links 334, 336 and 338 act as anti-extrusion rings for the elastic members 330, 332.
serves as a backup seal to the metal seal.

When the annular links 334, 336, 338 move further from the inclined position toward the horizontal position, the annular links 334, 33
Each end of 6.338, the inner and outer rims, moves to engage internal bore wall 61 and vertical sealing surface 140. This is not intended to mean that the annular links 334, 336, 338 are horizontal; the important thing is that
The inner and outer rims of the annular links 334, 336, 338 are biased between the internal bore wall 61 of the well head 24 and the vertical sealing surface 140 of the casing hanger 50. The inner and outer rims of each annular link are
Receives reaction forces from other suppressed loads. For example, circular link 3
The inner annular seal contact rim 356 of 36 presses against the vertical seal surface 140 of the casing hanger 50, and such contact creates an outer annular contact rim 358.
This creates a force in the well head 24 and moves it toward the inner hole wall 61 of the well head 24.
Rather than sealingly engage either of them, their sides will continue to descend until they abut adjacent annular links. This compression of the inner and outer rims requires the prevention of buckling or bending in the center of the annular link. Therefore, it is necessary to make the center part of the annular link strong with a diamond-shaped cross section to prevent buckling. Furthermore, annular links 334, 336, 33
8 would be horizontal, the dimensional tolerances between the inside diameter of the well head 24 and the outside diameter of the casing hanger 50 would be tight, and the annular links 334, 336, 338 Since the two-shaped portion 220 is horizontal and has a large angle, the two-shaped portion 220 can be easily released when the seal mechanism 210 is removed. The lower end 364 of the drive portion 218 and the upper end 372 of the lower cam portion 222 are sloped to prevent the respective annular links 334 and 338 from being horizontal.

Once the rims of the annular links 334, 336, 338 are sufficiently engaged with the internal bore wall 61 of the wellhead 24 and the vertical seal 1ij 140 of the casing hanger 50 to enable hydraulic pressure to be applied to the upper annular portion 134, the elastic member 330, 332
Please understand that this is no longer necessary. In such applications where there is a gap between the annular links 334, 336 and 338, the resilient members 330, 332 may be omitted. Moreover, such elastic members 330.332d,
It is understood that the annular links 334, 336, 338 can be replaced with spacers that can allow a predetermined amount of displacement.

Furthermore, in the present invention, the elastic members 330, 332 are not limited to elastomeric materials, but may be formed from other elastic materials, such as Grafoll, an all-glassite backing material manufactured by Dapon. Graphoil is particularly used in applications where fire resistance is desired.

This graph oil is located in Great, Essex, England.
F. Russell of Ranmou (F.

W, Ru5s*1) (Precision Products Limited)
ts Ltd, )) K. ``Graffoil Ribbon Pack, Universal Flexible Graphite Backing for Pumps and Bulbs'' and ``Crane Pac Packaging'' by Morton Group, Illinois, USA.
``Graph Oil・'' by Kinjr Company)
This is described in documents called "Brand Backing", and these documents are used as reference.

Alternatively, if a metal-to-metal seal is not desired, channels 368, 370, and 374 may be filled with elastomeric material to provide a primary metal-to-metal seal against internal bore wall 61 and vertical sealing surface 140 as described in the above embodiment. It should be understood that rather than sealing, a primary elastomeric seal can be performed; if the elastic member 330° 332 is the primary seal, the annular link 3
34.degree. 336.338 becomes the primary backup for the elastic members 330.332 and becomes the energized nine backup ring for the elastic members 330,332.

In such a case, the backup seal will not slip out of its correct position.

This invention is 1os sKe/4 (15,000pat
) and therefore the sealing mechanism 2
It is an object of this invention to pre-energize the seal mechanism 210 by applying 20,000 psi (1406'#/d) of compression to the sealing mechanism 210 above the expected operating pressure.

Seal mechanism 210 is actuated by torque and hydraulic pressure to provide 20,000 psi of compression. At the beginning, about 1383km (10,000ft-1b
An initial torque of s) is applied to the drill string 236 at sea level 18. This torque rotates the drill string 236 and transmits the torque to the threading tool 200.
As a result, a thrust is applied to the sealing mechanism 210. In particular, drill string 236 rotates mandrel II 230, which in turn rotates outer sleeve 250 via spline connection 320. Outer sleeve 250 drives packing nut 182 through the connection of lugs or grooved upper end 198 and grooved lower end 308. The packing nut 182 presses the drive portion 218 by transmitting thrust through the bearing mechanism 205. Since the presser mechanism 212 has moved to the pressing position and has reached its lower limit with respect to the latch ring 144 in advance, the sealing mechanism 210, more specifically the two-shaped portion 220, is compressed between the drive portion 218 and the lower cam portion 222. . Such a torque l K j Kuti approx. 68,0
A load of 40 Kg (150,000 lbm) is applied in the axial direction.

The two-shaped portion 220 is compressed between the drive portion 218 and the lower cam portion 222, so that the annular link 334°336.3
As 38 moves to a more horizontal position, the elastic members 330,3
32 is compressed between annular links 334, 336 and 338. When such compression is performed, the elastic member 330
, 332 begin filling nine channels formed to accommodate them between the annular links 334, 336, 338. The amount of elastomeric material in the elastic members 330, 332 is similar to that of the annular links 334, 336, . ．． 338 moves into the horizontal position of the lid as these move against the inner hole wall 6 of the well head
1 and the vertical sealing surfaces of the casing hanger 50 to function as a metal protrusion prevention mechanism that prevents the elastic members 330 and 332 from protruding. In particular, the inner annular contact 382.38
4 prevents the inner elastic member 332 from protruding, and the annular contact portions 386 and 388° prevent the outer elastic member 330 from protruding. In this way, the protrusion prevention seal includes the elastic member 330,
332° is initially formed by the annular links 334, 336, 338 before being able to project beyond the annular contacts adjacent to them. Resilient members 330, 332 have the appropriate volume and shape of elastomeric material so that when seal mechanism 210 is compressed, resilient members 330, 332
It is important that the metal anti-extrusion seal is formed before the annular contacts 382, 384, 386 and 388 are crossed.

In particular, the purpose of applying w-period torque is to use the elastic member 330°332
to form a back seal by setting the inner hole wall 61 of the well head 24 and the casing hanger 50.
is not intended to form a metal-to-metal seal between the vertical sealing surface 140 of the

Frictional losses within the riser string, blowout prevention stack, and drill string itself, as well as various thread loads, such as at threaded portion 118, and initial torque may not provide a perfect metal-to-metal seal for sealing mechanism 210. . Further, such friction loss is caused by the sealing mechanism 21 through the drill string 236.
The compressive load that can be applied to 0 is limited.

Hydraulic pressure is combined with torque to cause the seal mechanism 210 to provide the desired compression, thereby causing the seal mechanism 21
0 metal-to-metal seal is possible. The blowout prevention mechanism 40 schematically shown in FIG. 4A includes an upper annular portion 134
A pipe ram 34 equipped with a kill pipe 38 on the F side that communicates with the pipe ram 34.
have.

The kill line 38 is typically located below the lowest pipe ram. If for some reason the blowout line 36 is located at the bottom of the blowout prevention mechanism 4o, hydraulic pressure is applied through the blowout line 36.

When applying pressure to the upper annular portion 134 through the kill line 38, it is necessary to keep the upper annular portion 134 sealed. Although FIG. 2A shows the kill conduit 38 being located in the same plane as the ibram 34, it is actually fabricated at an angle of 90'.

In such a case, pipe ram 34 is closed to seal drill string 236 and mandrel 2 as described above.
30 and the sleeve 240 are O rings 264.266
There is an O-ring 292.29 between the sleeve 240 and the inner peripheral surface of the hole 272 of the casing hanger 50.
4, and the sealing mechanism 210 is sealed by the upper annular portion 1.
Provide an initial seal across 34. It is thus possible to apply hydraulic pressure to the upper annulus 134 through the kill line 38.

a drill '1, such as drill string 236;
The helical effect created by applying torque to the string typically results in
000 ft-1bs) can be transmitted through the underwater drill string.

In this invention, the drill string 236 has 138
If a torque of 3Kem (10,000ft-psi) is applied, the
) is formed across the upper annulus 134 to withstand hydraulic pressure. With such a relatively low pressure seal, pressurizing the upper annulus 134 further compresses the seal mechanism 210 to strengthen the sealing engagement with respect to the upper annulus 134 and to withstand even greater hydraulic pressure.

The metal annular bi-shaped part 220 having an annular link 334° 336, 338 has an annular link 334, 336, 3
38 is 4m to 1383 (10000ft-1bs)
The torque of 141 to 211 (200
The elastic members 330, 332 are designed to be sufficiently thin to form a metal-to-metal seal that can withstand hydraulic pressures of 0 to 3000 psi (0 to 3000 psi).

The range of pressure applied to the sealing mechanism 210 is
This is the range obtained by adding the annular seal portion of the seal mechanism 210 to the diameter of the drill string 236 from the diameter of the O-ring 264 to the diameter of the drill string 236. The area of the annular seal depends on the size of the well head and casing hanger, so when setting the applied pressure, only O
The difference in pressurization range between ring 264 and drill string 236 is varied. In this way, a predetermined compression force can be applied to the seal mechanism 210 by changing the difference in the pressurization range. For example, the difference in diameter above is 1
It can vary from 27 to 254 inches (5 to 10 inches).

By applying hydraulic pressure, the pressure can be increased to 1406'f/d without exceeding the pressure design limits of each mechanism of the well head system.
The advantage is that it provides an axial load that can apply pressures of (20,000 psi) to the seal mechanism 210. Patchkin nut 182 after applying hydraulic pressure
When torque is also applied to the sealing mechanism 210, the sealing nut 182 descends as the sealing mechanism 210 is lowered by the hydraulic pressure, thereby preventing the sealing mechanism 210 from loosening when the hydraulic pressure is released.

High torque for drill string 236, e.g. 13831m
It is important to apply a torque of (10,0001 b) so that the packing nut 182 follows the downward movement of the seal mechanism 210 without interfering with it. This kind of process is Patsukin Nut 182
is rotated sufficiently and the sealing machine 411210 receives 1406'/d.
(20,000 psi) (D Gradually and continuously increasing the oil pressure at the stage where the compressive force is applied is repeated from K.

The threading tool 200 is a device that has both the function of applying torque to the pressure sealing mechanism 180 and the function of assisting when applying hydraulic pressure to the pressure sealing mechanism 180.

When the drill string 236 is rotated to the ninth point transmitting torque to the pressure sealing mechanism 180 through the threading tool 200,
Initial sealing engagement of the sealing mechanism 210 in the upper annulus 134 between the well head 24 and the casing hanger 50 is made, which allows hydraulic pressure to be applied to the upper annulus 134 to further compress the sealing mechanism 210. Ru.

As the oil pressure in the upper annulus 5134 gradually and continuously increases through the kill line 38, the sealing mechanism 210 becomes more compressed and tightens against the internal bore wall 61 of the wellhead 24 and the vertical sealing surface 140 of the casing hanger 50. Seal engaged. Also, as the degree of seal engagement increases in this way, the sealing mechanism 210 is provided with sealing performance against pressure applied to the annular portion with the same size. Thus, the hydraulic pressure through kill line 38 is approximately 1
Kill line 3 is gradually increased until K is subjected to a compression force of 406"4/cd (20,000 psi).
The hydraulic pressure applied to the upper annulus 134 through 8 must not exceed the design pressure limits of the system.

All systems have standard operating pressures that are not exceeded during operation. The system of the present invention is 10 s
It is designed for an operating pressure of sKp/i (x s, o o o pss), so the oil pressure in the upper annulus 134 to fully move the sealing mechanism 210 is 1406'
f/, 4 (20, Oo o psl) is desirable, but the limit cannot exceed f 1055'/d (15,000 pal). The present invention is 10 s s Kg/
1406 to the sealing mechanism 210 without hydraulic pressure exceeding l* (t s, ooo pat ) @/, i (20,
000 psi) can be applied.

The oil pressure in the upper annular portion 134 increases steadily, causing the sealing mechanism 211) to reach 1406" f/d (20,000 psi).
) is applied to the drill string 236 and transmitted to the sleeve 250. 1383Kpm (
With a torque of 10,000 fft-1b), the packing nut 182 is inserted into the upper annular portion 13 through the threaded portion 204.
4 along with the seal mechanism 210. When the hydraulic pressure in the upper annular portion 134 is released through the kill pipe 38, the casing hanger 5
By screwing with the threaded portion 204 of 0, the cool mechanism 210
140611/a (20,000 psl
) to prevent release of pressure.

After the initial torque is applied by the ring 236, it is necessary to make a sealing contact. If the elastic members 330 and 332 do not make sealing contact, when hydraulic pressure is applied through the kill pipe 38, the hydraulic pressure will escape to the lower annular portion 130 side through the seal mechanism 210. However, elastic member 330.33
The seal according to No. 2 only needs to be capable of sealing against an increase in the hydraulic pressure through the kill line 38, for example, about 35 Kf/d (500 psi). After the initial sealing is performed, when the hydraulic pressure is further increased to pressurize the two-shaped portion 220 and the elastic members 330 and 332, the internal hole 116
1 and vertical seal surfaces 140 are further strengthened.

The seal actuation mechanism as described above is simpler than conventional mechanisms. The conventional actuation mechanism is to press down through the drill string to actuate an internal piston mechanism, which applies pressure through the piston mechanism, the end of the hole in the drill string is sealed by a dart member, and then through the piston mechanism Pressure is applied to the seal. Although such conventional actuation mechanisms could be utilized with the present invention, the present arrangement has significant advantages over the prior art.

It is necessary to increase the initial torque applied to the drill string 236 after the pipe ram 34 of the blowout prevention mechanism closes, and the rubber contact between the pipe ram 34 and the drill string 236 does not result in friction losses due to metal-to-metal contact. However, this results in some additional frictional losses. Therefore, if possible, an additional torque is applied to the drill string 2 in addition to the initial torque to compensate for such friction losses.
It is also possible to add to 36. However, the drill string 236 will rotate with the pipe ram 34 in the closed state. Wellbore fluid in the annulus between the riser and the drill string 236 is transferred to the interface between the pipe ram 34 and the drill string 236 when the blowout preventer 40 is closed. Therefore, 1383Kfm (10,
000ft-1bS) is considered to be substantially unchanged.

If it is necessary to reduce the friction between the pipe ram 34 and the drill string 236 for a special purpose, a special pipe ram (not shown) is connected to the drill string 236, and the pipe ram 34 has a rotating member. The fixed tubular portion may be engaged to allow torque from the pipe ram 34 to be transmitted through the rotating member. In such a special vacuum seal, a rotating seal part is provided between the stationary part and the rotating part to prevent fluid leakage.

Figures 5A, 5B, and 5C show 406.4■
(16 inch) casing hanger 420 and 339.
7 vm (13”76”) casing hanger 5
A casing hanger 400 of 0 and 244.5 inches (9'/a inch) and a casing hanger 410 of 177.8 inches (finches) are shown fully assembled. In FIG. 5B, the casing hanger 50 is in a press-sealing position, which corresponds to the moved press-sealing position of the press-seal mechanism 180 described in connection with FIGS. 1-g4.

244.5 garden (9'/s inch) casing hanger I
j 400 is the upper end 402 of the casing hanger 50
It is supported by The casing hanger 400 has a pressure sealing mechanism 404 that corresponds to the pressure sealing mechanism 180 of the ti casing hanger 50. 177.8 finches of casing hanger 410 2445 m1 (9'/
(@inch) is supported at the upper end 412 of the casing hanger 400. The casing hanger 410 has a pressure sealing mechanism 414 corresponding to the pressure sealing mechanism 180. Figures 5A and 5B show the locking groove of the ti Mirael head 2, that is, $68 for the casing hanger 50, #1I406 for the casing hanger 400, and the casing hanger 41.
11416 for 0 is shown.

Casing hangers 400 and 410 do not require a shoulder ring, such as shoulder ring 128 for casing hanger 50, since the loads supported by casing hangers 40G and 410 are small, and therefore do not require a contact bearing area as required for casing hanger 50. is not required for casing hangers 40G and 410. The casing hanger 5o requires a 100- contact surface which is not required for the casing hangers 400, 410. Additionally, the shoulders of the casing hangers 400, 410 are square and project evenly over the top of the supporting casing hanger.

FIG. 5C shows a removable casing hanger support mechanism, that is, the second CI! Another example of the closed housing seat 70 shown in FIG. In FIG. 50, closure housing seat 420 is lowered into bore 60 and connected to closure tooth 66 of well head 24. In FIG.

Below the 508cm (20 inch) casing (conductor casing) there is a formess where the 508cm casing cannot support the pressure due to the weight of the mud holding down the pressure in the bottom hole. . To prevent the destruction of such formations due to the weight of mud, 339
．． 406.4 holes (13”/s inch) were drilled before drilling holes for the 7 dew (13”/s inch) casing (casing hanger 50).
6 inches) of casing string through the formation. The closed housing seat 420 is 406.4■ (
16 inch) casing is suspended. Thus,
The closed housing seat 42G doubles as a support shoulder for the casing hanger 50 and a casing hanger for the 16 inch casing 422.

The closure housing seat 420 has an annular cylindrical ring 424 and a back-off ring 426. Cylindrical ring 42
No. 4 has closing teeth 428 on its outer surface which are similar to the closing teeth 76 described in connection with the closing housing seat 7o. The cylindrical ring 424 also has an upwardly sloping conical seat or support shoulder 430 that locks the back-off ring 426 . The cylindrical ring 424 further includes the closure housing seat 42.
0 in the well head housing 46, it has a plurality of dogs 432 that are substantially similar to the dogs 92 shown in Figure 111EZc. The cylindrical ring 424 also has a casing string 4 of 4064 mm (16 inches).
It has a box end 434 that threads into the upper pipe section of 22.

A retaining hole 438 is formed in the upper part of the cylindrical ring 424 to receive the pin end 440 of the back-off ring 426. The back-off ring 426 has a threaded portion on its outer surface that is threadedly engaged with a threaded portion formed on the inner surface of the retaining hole 438 of the cylindrical ring 424 at a portion 442 . back off ring 42
6 has an upwardly facing support shoulder 450 which engages the downwardly facing shoulder 132 of the casing hanger 50. An annular groove formed on the outer periphery of the upper end of the back-off ring 426 includes an O2 for sealing between it and the inner hole wall 61 of the well head 24.
Rings 444,446 are attached. A retaining hole 438 of the cylindrical ring 424 is located in the annular groove formed in the upper part of the threaded portion 442 of the bottle end 440 of the back-off ring 426.
O-ring 452.45 for sealing between the wall surface of
4 is also installed. 0 ring 452 and 0 ring 4
54 is provided with a ninth test port 456 for testing the back-off ring 426.

406.4 m (16 inch) casing string 4
Closed housing seat 420 for cementing 22
A channel 435 shown by a broken line in FIG. 50 is formed in the channel 435. The flow path 435 is formed between the flow passage portion of a closing groove such as the groove or gap [1186, 87] between the closing housing seat 70 and the well head 24 shown in FIG.
It has nine series of grooves arranged at intervals of nine meters around the entire circumference. The groove around the annular flange 85 is designed to prevent the closing housing seat 420 from slipping out of the well head 24. $86.87 is also narrowly formed.

A back-off ring 426 is installed to seal off the back-off upper annular portion 134 after cement filling. To test the back-off ring 426, the pipe ram of the blowout preventer is closed to seal the through odor at the bottom of the test port 456, and then the upper annulus 134 is pressurized. Moshi well head housing 46 and back off ring 426
The connection 4L< is the back off ring 426 and the retaining hole 438
If there is a leak between the
The pressure cannot be increased. Moreover, the amount of oil flowing into the upper annular portion 134 from the kill pipe 38 also increases. At the stage when the well is completed, the u pressure is 351.6 ”41
/cd (5,000 psi) or less, so the back-off ring 426 need not be capable of forming a pressure seal.

It will be understood that in such an embodiment with one closed housing seat 7o and one casing hanger 50, the closed housing seat 7o and the casing hanger 50 can be lowered into the wellbore in one step. sea bream. The casing hanger 5o is configured, for example, with closing teeth that directly mesh with the closing teeth 66 of the well head 24.

In an embodiment in which the cylindrical ring 424 of the closing housing seat 420 is lengthened in the longitudinal direction, the sealing mechanism 210 and/or the holding mechanism 212 are connected to the closing housing seat 420 and the well head. The well head 24 may be directly disposed between the well head 24 and the well head 24 for sealing and/or pressing engagement. In such a case, backoff ring 426 is no longer needed.

Since many different embodiments can be constructed within the scope of the inventor's ideas as taught above, and many variations can be made to the embodiments described above in accordance with the description requirements set forth by law, It is to be understood that the description is to be construed as illustrative only and not in a limiting sense. That is, the present invention is not limited to the embodiments described for illustrative purposes;
Modifications may be made within the scope of the claims.

(1st Great King ((= Bald Order)

[Brief explanation of the drawing]

The figure shows one embodiment of this invention.
Figures 2A, 2B and 2C are cross-sectional views showing the main parts of Figure 1, and Figure 3 shows the closed housing seat as part of the well head. FIG. 3A is an enlarged view of the key mechanism shown in FIG. 5, FIG. 4 is an enlarged sectional view of the seal mechanism, and FIG. 5A, 5B, and 5C are enlarged sectional views similar to those shown in the figure, and are a series of sectional views showing three casing hangers attached to a well head in a press-tight state. 10... Well hole 12... Seabed 16...
・Drilling ship 20...Guide base 22...
・Conductor casing 24... Well head 26... Blowout prevention stack... y 28°-, -qy>'4''30°°°85
4...Viphum 40...Blowout prevention mechanism 4
6...Well head housing 50.400.410...Casing hanger 52...
- Shoulder part 56 - Shoulder part 61... Inside 1111 64... Locking notches 66, 7
6, 428...Closing tooth 70.420...Closing housing seat 72...Ring 78...Key mechanism 80
．． 430, 450...Support shoulder portion 82...Glue ring 84...Segment 85...Annular flange portion 86.87...Gap 9
2...Dog 110...Tree body 112.
...Lower neck part 116...Shoulder part 118...
Threaded part 120... Annular groove 126... Threaded part 128... Shoulder ring 130... Upper annular part 134... Upper annular part 140.380.3
82...Overlapping sealing surface 144...Latch ring 180.404.414...Press sealing mechanism 182"°
°Packkinnaft 200...Through ^204...Screw li 205...Bearing mechanism 210
...Seal mechanism 212...Press mechanism 218.
...Drive part 220...Two-shaped part 222...
・Cam part 230...Mandrel 236...Drill string 240...Sleeve 250...Outer fl
ay leap 264.266.292,294,444,446,4
52,454...0 ring 268...Ring flange 274...Annular shoulder 280...Dog 298...Snap ring 518...Flow port 330.3!12.
...Elastic member 334.336.358...Annular link 342, 344.346...Connection ring 421...
Cylindrical ring 426... Back-off ring 458
...Test boat applicant Smith Internacional Sonal Inc. Holley Derado agent Patent attorney Hideo Oka 1)
Engraving of Hiko's drawing (content: no changes) Continuation of page 1 Priority claim @February 19, 1982 ■United States (US) [
] 350374 (l Author: Arthur Alston 354 Agenas Drive, Ventura, California 93003 United States of America Mekoma Procedural Amendment (Method) July 20, 1973 Patent Office Counsel Kazuo Wakasugi 1 Indication of the Case 1978 Tosho 1st 02nd evening'l No. 78'Wame, related person, protector = Pwe 1L67 music, 3 person who makes corrections

Claims (1)

[Scope of Claims] (1) A seat structure for supporting a plurality of pipe hangers in a well head for suspending pipes in a well, which includes a cylindrical part interposed in the well head, and a connecting mother tank provided on the cylindrical part to freely connect the cylindrical part to the well head; and a connecting mother tank provided on the cylindrical part to freely support the lowermost pipe hanger. Shoulder m
A seat device characterized by having a sakaki. (2) The shoulder mechanism cannot be supported within the well head, and the load of the pipe hanger and the pipe, for example
Claim 1F, characterized in that it has a support part capable of supporting an operating pressure of 9fi (15,00 [1 psi)] at 054.7! : The seat device described in item 1. (3) The front shoulder mechanism is designed to reduce the charge of the pipe hanger and the suspended pipe without exceeding the material yield value for vertical compression of the cylindrical part with the fFi induction of the wellbore and the Bunjincho simple support part. A seat device according to claim 1, characterized in that it has a seat device. u> * Recorded as h, approximately 2.721,600
1. The seating device according to claim 1, characterized in that it has a shoulder portion capable of supporting a direct-pressure thin rod weighing more than KQ (6,000,000 pounds). (S) The M-era shoulder pattern is at least approximately 53 meters in the horizontal direction (
2. The seat device of claim 1, further comprising a harp-shaped support shoulder having an effective thickness of 1.3 inches. (6) The seat electric appliance according to claim 11, characterized in that the shoulder mechanism has a sloping clear shoulder portion having an inclination angle of 50” or more. The seating device according to claim 1, characterized in that a running l!l fixed structure is provided for fixing the formation part in the well head. Claim #1 characterized in that a continuous feeding mechanism is provided to the sagittal S so as to be detachably attached thereto.
I Zero-dust device as described in Section 1. (-) - The connecting fence structure has threaded portions on each of the head and the support member that are screwed together by the rotation of the support member.Claim $1 The seating device described. (2) The seat device according to claim 1, wherein the III coupling mechanism functions by rotating the cylindrical portion by, for example, 60 degrees. (2) The seat device according to claim 1, wherein the connecting mechanism has closing teeth. (2) The seat device according to claim 1, wherein the interlocking mechanism has teeth shaped so that stress is applied evenly over its entire length. υ A support mechanism for supporting a hanger for suspending a pipe in a hole, comprising a head portion ν, a support member inserted into the head portion and a pre-prepared receiver for locking the hanger; A plurality of leadless threaded portions are provided on the inner periphery of the head member and the outer periphery of the support member at one circumferential interval, and the threaded portions on each side are mutually connected to the threaded portions of one of the members. When the threaded portions on each side are screwed together, axial force is prevented from being applied to each of the members, and the supporting member engages with the head member to prevent the cocoon retaining member. The support mechanism is characterized in that the hanger and the pipe can be supported within the hole. (b) A support device for supporting a pipe hanger for suspending a pipe in a well, comprising a head member, a support member that locks the pipe and the hanger and can be inserted into the head member, and the head. and an AS structure provided on each of the supporting members to allow each of the members to be attached and detached by rotation of the supporting member, and the head includes a plurality of grooves arranged at intervals of these teeth. A support device characterized in that it is formed so as to be able to fit between the grouping teeth of the member. as Each tooth of the tooth mechanism is configured such that it can be completely brought into contact with one rotation or less of the support member. Support as stated in item 14 *W. (To) The support device according to claim 14, wherein each tooth of the tooth mechanism is formed in an inclined shape with a lead angle of zero, and a wide shear area is given to each tooth. . α′I) The support device according to claim 14, wherein each of the teeth of the support member is formed so as not to interfere with each tooth of the front FD head member. . (To) Each tooth of the tooth structure is formed into a rounded shoulder shape to prevent rock debris from a well from accumulating on each tooth. 14311. The support device according to No. 14311. The grouping tooth has a segment, and when screwed together by rotation, the segment of the head member is cleaned by rotation of the segment of the support part. A support device according to claim 14. 15. The supporting eel mackerel according to claim 14, wherein each tooth of the tII mechanism is formed in a shape that can evenly distribute the stress applied to all of the five isthmus teeth. (2) Each of the -Ial 14- has the same length, and the number of grouping teeth of the head member is equal to the number of the teeth of the head member. # The number of grouping teeth is equal to the number of grouping teeth of the member, and the head member and the support member have one grouping tooth, so that stress and load are evenly distributed to the mass. The support device according to claim 14r0j&, characterized in that: (2) The support device according to claim 14, wherein the head member and the support member each have six grouping teeth and six gaps. (2) The self-mounted fork M device as claimed in the present invention, wherein each of the grouping teeth has six rows of teeth. - Each tooth of the support member is configured to be longer than each tooth of the head member in one axial direction to prevent early screwing between the support member and the head member III. The supporting device according to claim 14 characterized by: (to) The support device according to claim 1i1414, wherein each of the support member and the head member is formed with a cylindrical non-threaded portion in a nested manner. (to) Claim 14, wherein the grooving teeth of the head member are formed in substantially the same range in the circumferential direction as the grooving teeth of the support member.
Support device as described in section. 15. The support device according to claim 14, further comprising a rotation prevention mechanism that prevents relative rotation between the head member and the 1IfJ support line support. (To) Patent W4* described in Section 27 of the scope of Patent W4*, characterized in that one of the head member and the support member of the rotation stopping mechanism has a locking member for stopping the other member. Support device. The feature ff1f is characterized in that the rotation stopping mechanism is configured to operate when the supporting member rotates one rotation or less.
#Support device according to claim 27. 11 (To) To stop Jull from rotating on its own, either one of the above 71 members or the Bunshin member described in #i has a movable member that can enter into the void formed in the other member. Special #1F steel requirement range @27
Support device as described in section. (2) The movable member controls the relative axial separation movement of the support member from the head member in a state in which the movable member is not in contact with the head member, and the relative axial movement of the support member and the head member. The support W according to claim 30 is characterized by scales that move to allow the movement of these members by relative rotation rather than movement!萱. 31. The support device according to claim 31, wherein the support member 11a has a hanging mechanism for moving the movable member to the non-latching position. (2) Due to the presence of the passage of the grooving teeth of the Y-shaped member between the grooving teeth of the head member, the beaking tN of the teeth *St when the support member is rotated.
Claim 1: A ninth support device for supporting a row of pipe hangers for suspending pipes in a hole, the ninth support device having a ninth support device for supporting a row of pipe hangers for suspending pipes in a hole, and a ninth support device for securing a head member and a lowermost pipe hanger. 1 a support member having a support portion; and a round second support member that is attached and detached from the head member to each of the support members and that supports the support member with the head member.
tooth e*ns having a support part, and the area of the first support part and the second support part is such that the load due to the electric charge of the pipe hanger and the suspended pipe and the working pressure of the wellbore is the same as that of the head member and the second support part. A support device characterized in that the support device is set to be wide enough so that the material yield stress for vertical compression of the support member is not exceeded. (To) The head member is a standard member for drilling a well hole for the pipe suspended from the lowermost piping hole. At least 446.1U (
35. The support device according to claim 34, characterized in that the support device has a hole diameter of 17 J16). (To) The head member and the support member are formed of a material having a high yield stress value of at least 5976% (85000 p@i). The fork holding part F1272
The patent claim il! is capable of supporting a load exceeding 1.600 meters (6,000,000 1v)! The writing device described in the 54th section of s Houki. 35. The support device according to claim 34, wherein the island 1 support part has an annular shoulder part inclined at an angle of 301 or more to the III period support member. Zeng: The tooth mechanism includes a plurality of annular structural segments in front of each of the head member and the support member, and the capillary segment of the support member passes through the middle of the m structural segments of the head member. 34. The supporting device according to claim 34, characterized in that the support device has a continuous structure. A cylindrical member κ formed in one member and slidably inserted into the hole is provided to provide a metal material V-κ between the cylindrical member and the inner wall of the hole. The structure is 1, consecutively arranged, and each frustoconica k (f
(1189) a plurality of metal 1189 rings each having a conical shape that can be shaped into a circular shape, (1) a round annular shoulder provided on a cylindrical member, and (9) an actuating member attached to the cylindrical member; the annular shoulder and the actuating member have surfaces facing each other to engage a metal ring at an end of the metal ring row when sealing is achieved; The outer diameter of the ring, the annular shoulder, and the actuating member are set smaller than the diameter of the hole, and the actuating member has a drive mechanism that applies an axial force to the actuating member. The method is characterized in that the inner and outer ends of the metal ring are moved by engagement with the row of metal rings to engage the inner and outer ends of the metal ring in metal-to-metal sealing engagement with the cylindrical member and the inner wall of the hole. I'm afraid the sticker is fake. - The metal ring has a sufficient width in the radial direction with respect to the inner part and the outer end thereof, and is able to butt against and sealingly engage the cylindrical member and the inner part M of the hole, so that a small circular shape can be formed by deformation. 41. The V-ru device according to claim 40, characterized in that it is configured to form an angle. - The sealing device according to claim 40, characterized in that the 4N sea bream ring is compressed by exceeding a peak-to-peak value between the shoulder portion of the 4N ring and the actuating member. 15II&lli Gold II4 ring, the annular shoulder and the member O are provided with an annular ring forming a connecting link between the annular shoulder and the 111st material. m of a patent claim characterized by
1ll Item 40 IDtl- device. - The mlI of the patent claim, characterized in that the gold sea bream ring rubs against each other to form a coral-shaped ring that accommodates an elastic sealing member! 41. The sealing device according to claim 40, characterized in that a spacer mechanism is provided between the metal rings that meet each other. - a cylindrical member slidably inserted into a hole formed in one of the adjacent members to provide a metal-to-metal seal between the cylindrical member and the inner wall of the second member; V-
It has an annular body integrally having an upper 4N annular part, an intermediate part, and a lower annular part, and the intermediate part is formed into a frustoaonioal shape, and its upper end is attached to the upper hook. The lower end of the lower part of the annular part is integrally connected to the upper part Ml@ of the lower part of the annular part, and compressive force is applied to the annular part to make the front 6 upper part and the lower part of the annular part thicken from each other. A driving mechanism is provided for deforming the cm-diameter part to form a small circular angle by moving the intermediate part, and the intermediate part engages the cylindrical member and the inner wall of the hole with a metal-to-metal seal. A sealing device characterized in that it has a structure so as to perform the following functions. 47. The sealing device according to claim 46, wherein the intermediate portion is formed in a truncated shape having an upper frusto conical link, an intermediate frusto conical link, and a lower frusto conical link. Claim 4, characterized in that the intermediate part has a series of fist conical links oriented in alternating directions with respect to the fist conical field @rliJK.
V-ru mounting according to item 6. - V of Claim No. 48 JJI Journal, characterized in that an odd number of said frustoconical links are provided.
-L device. A sealing stirrup for V-ru between a casing hanger and a well bed, each of which is adjacent to the 792)
:l Nikas,, (fruatoconical) A plurality of gold Xlls piped in a fast-hard row with their inclination directions facing each other in the direction of KK finances and each having an inner side and a sex!
a round annular member provided on the casing hanger, and an operating member that reciprocates along the casing hanger, and the outer diameter of the metal ring, the one-shaped member, and the operating member The hole diameter is smaller than the hole diameter of the well head, and when the 111th control ring row is distributed between the coral-shaped member and the drawing line actuation member so that the actuation member works toward the 1-shaped member, A V-hole apparatus characterized in that said inner and outer rims of a metal w-ring are configured to move fully radially and outwardly, respectively, into sealing contact with said casing hanger and said well head. Claims characterized in that the gold ring is formed into two shapes having an upper twisted conical ring, an intermediate twisted conical ring, and a lower twisted conical ring! 51. The V-leur device according to item 50. - The V-ru device according to claim 50, characterized in that an odd number of said metal rings are provided. Hammer The metal ring exerts a metal-to-metal ring of at least 210.9% (&0OOpsi) when a torque of <1383 (10,0OOft - 1b8) is applied to the crop member. 51. The sealing device of claim 50, wherein the sealing device has a thickness that can be provided between a casing hanger and the well head. Claim 50'1, wherein the ring made of gold W14 is made of a metal having a yield value that is less than half the yield value of the material forming the casing hanger and the well head. V-
device. (To) The metal ring is made of a ductile metal material that can be easily deformed when the V-ru is engaged.
I,! : The V-ru device according to claim 50. - The metal ring is formed from a ductile material so that the rim can be plastically deformed and bit into the uneven portions of the case hanger and the well head O-jo. 51. The V-leur device according to clause 50. 1ii/I-1n The V~R Gosetsu according to claim @encirclevg50, characterized in that an annular link is provided for connecting the metal rings that meet each other. #i1 The metal rings at the ends of the metal ring rows are connected to the annular member and the actuating member, and the annular link connects the metal ring to the annular member and the actuating member. [Claim 5 characterized in that the WII dynamic connection link is configured to be connected to a barrel]
The sealing device according to item 0. - The ring hanger for each ring has a width that allows the bending of the other ring link, and the ring hanger in which the rims of the adjacent metal rings are close to each other is provided. and the V-hole device according to claim 58, characterized in that it is configured to be able to come into contact with the well head. ■ A ring constituting a mechanism for accommodating a rounded annular elastic member that forms an elastic seal between each of the annular links and the adjacent metal ring, the metal ring, and the well head. A sealing device according to claim 59, characterized in that: (2) F1 hit #w1 in the darkness of the metal rings that are next to each other]
51. The V-ru adjustment according to claim 50, characterized in that each of the mating gold rR9 rings is provided with a ninth subway 16 for setting the amount of movement. (2) The sealing device according to claim 61, wherein the spacer mechanism has an annular elastic member. 62. The sealing device according to claim 62, wherein the III elastic member is made of an elastomeric material. Shaft: Claim 6, characterized in that the elastic member is formed of grafoil.
V-le device according to item 5. - Adjacent] The gold that matches! 51. The sealing device according to claim 50, wherein an annular elastic member is provided between the ll4llll rings. (To) The metal ring suppresses the protrusion of the elastic member.
The sealing device according to claim IK65, characterized in that the sealing device is configured to enable The volume of the elastic member is 1ltF depending on the volume of the square space between the casing hanger and the well spacing F, and the elastic member protrudes from the rim L!
44. Previously, the rim was configured to be in contact with the well head and the rim. 66. A sealing device according to claim 65. The elastic member Fim has a V-shaped cross-sectional shape.
Claim 1, characterized in that a leg portion (contouring the volume of the elastic member between the adjacent metal rings) is formed on the top thereof. ! Item 65: Kihoro's V-L device. - The elastic member F'i is coupled to the adjacent metal cylinder.Claim vg65
V-le casting as described in section. Elastic and metal-to-metal V-
A round drive mounting for driving the ring mechanism, including a moving member that protrudes into the annular portion and engages the sealing mechanism, and a torque transmission that engages with the moving member and transmits co-rotating torque to the moving member. a mechanism, the moving member is threadedly engaged with the casing hanger to transmit torque to the moving member in one direction, and the moving member is displaced downward a sufficient distance along the casing hanger. a hydraulic mechanism for energizing the sealing mechanism to seal the coral against fluid flow and applying hydraulic pressure to the sealing mechanism so that the metal-to-metal portion of the sealing mechanism The well head and the casing hanger and the metal seal can be engaged with the sushi and the said transfer! The IK drive device is characterized in that the 0 machine hole is smoothed to prevent loosening of the working shoulder of the V-leaf in the case of the seal mechanism. and a pump connected to said conduit for applying hydraulic pressure to the annular part. n The shear f torque transmission mechanism is 158 to the moegi 6 moving mechanism.
6KtJ! 1 (applying a torque of 10,000ft-1bl to the above-mentioned obstacle part
1) Claim 7 o
1. The drive device according to 1. (c) The hydraulic mechanism gradually increases the pressing force to
-le m1fRK1406.2% (20,OOOpgi)
70. The drive shaft mount according to claim 70, characterized in that the drive shaft mount is provided with a structure so as to be able to apply cD compression force. σ4 The pipe connected to the torque transmission mechanism 1Ilr period moving member and this pipe II! The drive device according to claim @70, wherein NIIk includes a rotation mechanism for one rotation. I7υ There is a V~ between the pipe and the well head.
75. The drive device according to claim 74, characterized in that the drive device is provided with a lever member. 6. The driving device according to claim 74, characterized in that a sealing member is provided between the pipe and the casing hanger. h. A lowering device provided on the pipe string for lowering the casing hanger and the casing into the subsea well head and operating the pressure sealing mechanism of the casing hanger, the lowering device being connected to the pipe string at one end and the other end. a mandrel pushed into the casing hanger; a skirt-like member provided on the mandrel;
This skirt-like member (a torque transmitting mechanism is provided and the press-seal is secured to the structure) and a part of the skirt-like member is inserted into a coral-like chamber formed between the mandrel and the casing hanger. a sleeve member extending VC between the mandrel and the 11JE casing hanger; provided on the sleeve member and driven by the mandrel;
A lowering device comprising: a latch mechanism that detachably connects the mandrel to the casing hanger. The lowering device according to claim 77, wherein the volcanic skirt-like member and the mandrel are connected by a spline so that torque can be transmitted. 79. The lowering device of claim 78, wherein each of the splines has a side opposite a lower end and is held by a retainer threaded onto the mandrel. 78. The lowering device according to claim 77, wherein the skirt-like member has a hoard sm for a passage through which wellbore fluid passes. A lowering device for lowering a casing to a well head below sea level, comprising a mandrel whose upper end is threadedly engaged with the pipe string and whose lower end is dimensioned to be received in the casing hanger, and the mandrel. a sleeve member provided on the mandrel and partially located between the mandrel and the casing hanger; and a sleeve member provided on the sleeve member for stopping the casing hanger and connecting the mandrel to the casing hanger. and a first position where the sleeve bending material and the mandrel melt and the latch aIls are locked, and a second position where the tick mechanism is released. Device. 82. The lowering device according to claim 81, further comprising a chest for holding the sleeve member and the mandrel on the mandrel the previous day. (c) The range number of the viscous punch i+1# characterized in that a sealing mechanism for sealing between the sleeve member and the casing hanger is provided between the sleeve member and the mandrel. The lowering device according to paragraph 81. Bowl The tick mechanism has a latch segment attached to a hole in the sleeve member, and
Claim 81, characterized in that the latch segment is adapted to be pushed radially outwardly through the retention hole and thereby engage the I-rope casing hanger. Descent device. @ The latch segment is SD
IIL! 85. The lowering device of claim 84, further comprising a retainer mechanism for retaining within the hole. M1! The U mandrel includes a biasing mechanism for biasing the latch segment into engagement with the casing hanger in the first position and a biasing mechanism for permitting radial inward movement of the latch segment so that the latch segment is forward 1 lrr! Kakeru 2
This table is characterized by having a *tq structure mechanism that allows the casing to be removed from the casing hanger and hanged.
Descending as stated in item 84 of the desired range ← 曾. Excitation: The lowering shaft of claim 86, wherein the biasing mechanism includes a nine radial annular projection on the mandrel for biasing the latch segment outwardly. Arrived. 87. The lowering device of claim 86, wherein said release button et has a groove-like skin provided in said mandrel for receiving said latch segment. - the latch mechanism has a cam mechanism for camming into the latch segment that is not engaged with the casing hanger when the forward sleeve member and the IiJ mandrel are in the 8143 position; Claim #'F Claim #! Decrease percentage position described in item 84. 2, characterized in that the sleeve member and the mandrel have a release for preventing the mandrel from moving to the first position after the mandrel has moved to the second position. A lowering device according to claim 84. eη The release mechanism includes a snap ring in the sleeve member that engages the mandrel when the mandrel and skirt member are moved to the second position. The lowering device according to item 90. B) A pressure sealing device installed in a well head and provided on a casing hanger, the device comprising a rotating member screwed into the casing hanger, and a rotating member provided on the rotating member to connect the casing hanger, the well head and an identification member housed together with the rotating member in the formed annular portion, and this 17! and a latch member installed on the casing hanger below the fixed member, and the fixing member is composed of an upper positive actuating part, an intermediate seal part, and a lower cam part, and these are made of Kinjo material in one piece. The lower cam portion is cam-engaged with the latch member by providing a torque transmitting hole that fits with the rotating member to be formed and allowing the rotating member to move downward within the annular portion. Pressure engagement with well head 7'? The press W! is characterized in that the intermediate seal portion is configured to engage the case V hanger with the seal after tightening and scolding. Ambiguous about seal 4. -Upward field of the lower cam part Fi of the latch member-〇1
The scope of claim @92 is characterized in that the IC is configured to have a downward slant (■) that intersects with the LIC so that the IC #I@-blood engages with the cam when the front lower cam portion is lowered. Pre-pressing N device described in Section 1. - comprising a mechanism capable of engaging the front gd casing hanger of the latch member #i to prevent the latch member from moving upward along the casing hanger; Repression sealing device. (To) The intermediate seal portion is alternately
(frustoconical) Patent claim 92 characterized in that it is constructed by integrally connecting frustoconical links forming an oblique shape and has a new surface Z shape.
The pressure sealing device described in Section 1. (4) A patent claim characterized in that the lower end of the upper actuating part and the upper end of the lower cam part have a frustoconical surface in the same inclination direction as the inclination direction of the adjacent distortion conical link. A suppression sealing device according to item 94. - A bearing mechanism is provided between the rotating member and the ITiT fixed member to facilitate rotation of the front rotating member with respect to the 111 fixed member. Suppressive sealing device as described in section. - The press sealing device according to claim 92, characterized in that the torque transmitting horizontal comb for transmitting torque from the rotating member to the fixed member is provided with a horizontal thrust bearing mechanism. - the establishing member has a @1 bearing portion opposite to the second bearing portion of the rotating member; and the thrust bearing mechanism is the pressure sealing device according to item $98; . (100) A pipe hanger that suspends a pipe from a well head and sealingly engages with the cylindrical inner wall of the well head, the pipe hanger suspending the pipe in a wellbore and having a small diameter portion at -m; FIi has a shoulder-like shoulder part provided in the small diameter part, and an annular ring that is pressed outwardly against the small diameter part, so that the shoulder part and the horizontal ring are frustoconical. ), and a plurality of 7-wost conical shaped gold l141 are formed in the small diameter portion between these wost conical faces.
The Kl rings are arranged in continuous rows with their frustoconical inclinations alternating. 14J1 and the 7 last conical field diagonal in the same direction as the 14J1 conical ring and the first conical surface of the shoulder part also form a hob conical angle of 1%, and the 1ltl annular ring is movable from a non-sealing position to a sealing position, and the annular ring deforms the metal ring row in the sealing position, and the metal ring is compressed to close the inner wall of the well head and the small diameter portion KV. A pipe hanger characterized in that it is configured to engage in a sealing manner. (101) A patent characterized in that the gold 4111!Jing row has a cross-sectional double-shaped cane that can be deformed when a compressive load is applied. (102) The metal ring is made of a ductile material that can be plastically deformed when the seal is engaged. Pipe hanger according to claim 100. (105) 149 The pipe hanger according to claim 100, characterized in that it has a collar-shaped link connecting the metal rings that fit together. (104) The gold I14 A separate annular link connects the four IIT gold maple rings at the ends of the axial ring row to the mating shoulder and the annular ring. Claim 103Qll is characterized in that it is designed to be formed.
Pipe hanger from the novel. (105) Each of the lowered rings and the gold ring adjacent thereto form a mechanism for accommodating an elastic member forming an elastic seal between the annular body and the well head. 104. The pipe hanger according to item 104, characterized in that: (106) A pipe hanger for suspending a pipe in a wellbore from a well head, an annular shoulder connected to the upper end of the pipe suspended in a wellbore and attached to the wellhead. an annular body having a section, a latch member provided on the shoulder section, a rotating member screwed into the annular body, an upper part, an intermediate seal part, and a lower cam part, and these are integrated. and a fixing member made of metal, and when the upper operating section is rotatably attached to the rotating member 11iI, the fixing member is attached to the front 1! KI in the annular part formed by the annular body and the well head
If arranged above the latch member, the fixing member is lowered within the beak by rotation of the rotating member, and the lower cam part engages with the latch member to secure the well head. ms+, so that the intermediate seal portion is pressed into engagement with the annular portion and the well head, and thereafter the intermediate seal portion engages with the annular portion and the well head. (107) M middle seal part 79
Frust conical links are integrally connected in series with alternating frust conical inclinations], and have two shapes in cross section.
The first claim characterized in that
Pipe hanger according to item 06. (108) The III shoulder fI/6 has a removable annular portion, and the chain annular portion has a downwardly facing foot conical support surface that engages the well head at 360”. Pipe hanger according to Item 106, where 'Fl'fm--required range.
Range of tR The pipe hanger according to item 108. (110) A seal fixing tF device for V-ruing and fixing a casing hanger installed inside the well head, which includes a rotating member screwed into the casing hanger, and an upper gIA operation intermediate seal part. and a lower cam portion, which are integrally made of metal, and is rotatably housed in the E@ operation tube with respect to the rotating member, and the a latch member disposed within an annular portion formed by the casing hanger and the well head and provided on the casing hanger below the ti1 constant member, and a latch member that engages the rotary member and locks the rotary member. Torque transmission flI that transmits rotational torque! the rotary member descends along the casing hanger and the front lower cam portion engages with the latch member, whereby the rotary member is pressed into engagement with the well head and the intermediate seal portion is closed. said casing hanger and said well head KV-ru engage to prevent fluid flow through said annulus, and said Ii! 11. A hydraulic mechanism is provided for sealingly engaging the casing hanger and the well head by applying hydraulic pressure to a constant member to further apply energy to the intermediate seal member, and the rotary member is configured to engage the casing hanger and the well head in a sealing manner. M- movement along the hanger @ (in violation of 1Ilr)
A seal fixing device characterized in that it is configured to prevent the intermediate seal portion from loosening when the hydraulic pressure is released. (111) The torque transmission m structure is connected to the rotating member at 138
111. The v-ru fixation device of claim 110, wherein a torque of 3 KtJffl (10,000 ft-1 b') is applied to form a seal within the annulus. (112) The pressure of the oil Et + cypress increases ≧ and the inside sea 4sK1406.2Yi (20,00
A standby FI characterized by scales that apply a compressive force of 0 psi)
f# I-required range The seal fixing device according to item 110. (113) A hanging device for suspending a pipe in a well, which includes a well head having an annular fixing part at the upper part, a round annular shoulder part, and an oversized inner part; a casing hanger having an annular support surface supported on an annular shoulder; a latch member provided on the casing hanger adjacent to the fixing groove in the support position WIK above the support surface; A pressure seal #19 is provided on the casing hanger above and has a rotating member and a 19 member.
l! The rotary member is fitted into the casing hanger, and is rotatably attached to the rotary member between the fmKr5 and is formed in contact with the casing hanger and the well head. The fixing member is located within the annular part, and has a V-ru part and a cam part mating with the latch member Vcf, and is attached to the casing hanger. Rotate the rotating member 1 rotation and move the *tX member and the fixed member forward!
Tl:! a torque transmission mechanism for lowering movement within the annulus, and the cam portion retains the casing hanger within the wellhead. The latch member is engaged in the fixing member 4, and the siI seal portion is compressed by the lowering of the rotating member. $'
- the sealing part sealingly engages the casing hanger and the well hept, and further includes a hydraulic machine* for applying hydraulic pressure to the fixing member, so that the sealing part is further energized and the well head and the front ffd casing are The rotary member is configured to be in sealing engagement with the hanger, and the rotating member is lowered along the casing hanger due to the operation of the seal portion, and when the hydraulic pressure by the hydraulic mechanism is released, VC@
A hanging device characterized in that the rotary rotating member is provided with a groove to prevent loosening of the seal portion. (114) The torque transmission m column in Ill is 1 for the rotating member.
383KQI! l(10,000ft-1b) (D
Torque: 77rl, t: K inside the annular part: 210.9
kVi (3,0OOp81) pressure seal part cj
Claim 11 characterized in that
The hanging equipment described in item 5. (115) The hydraulic mechanism has a maximum of 1054.7% (15,
000p! i) Gradually increase the pressure until it reaches 1406.2% (20,000p111) at the sealing part.
Hanging←placement according to item 116 within the hunting range characterized by scales that apply compressive force. (116) The seal portion has a metal seal portion that forms a metal-to-metal V-ru between the casing hanger and the well head.
The range of demands! Suspension mounting as described in Section 113. (117) The seal part has an elastic seal part in the metal seal mechanism, and a 4#11 elastic V-rule is provided between the casing hanger and the well head before hydraulic pressure is applied to the hydraulic mechanism. 11. The hanging device according to claim 11116, characterized in that the suspension device is configured to be able to serve *#Wf. (118) A main body having a chest attached to a well head; and a suppressing mechanism provided on the main body to press into engagement with the well head; A metal seal mechanism that engages the metal to metal V-le with the well head, and this metal seal mechanism! When the drive mechanism moves downward in the axial direction, the suppression mechanism engages the well head, and when the body aneurysm moves downward, the A casing hanger characterized in that a metal seal mechanism sealingly engages the well head. (119) A qf! characterized by having a torque transmission mechanism that transmits torque to the drive member, and a number of hydraulic mains that apply fluid pressure to the metal seal mechanism. Casing hanger for f'4 range No. 118. (120) having an axially movable sleeve with a downwardly facing shoulder and a movable fixing ring having an upwardly facing shoulder that engages the shoulder;
It has a fixing groove that accepts the FPd ring. Due to the lowering of the sleeve along with the lowering of the machine shaft, the shoulder of the downward facing jaw is exposed to the lower part of the shaft. ! 118. The casing hanger according to item 118, characterized in that the casing hanger is configured to be hung by cam-engaging with the i1 city ring to suppress and secure the well head. (121) The movable fixing ring and the bottom of the fixing groove are each formed with an slanted co-vaginal opening.
The casing hanger according to claim 120, which is mold. (122) A casing hanger as set forth in Claim No. 120, characterized in that each of the chests has a sloped cooperation surface. (12!5) A hanging device for suspending a pipe in a hole, which includes a well head member and a pipe that is inserted into the well head member to form a 7
9X): i Nikas,, (frustoconloi
l) a seat member having a shaped shoulder; provided on the well head member and the seat member, the seat member being rotated by less than 360 degrees to the well head member;
A tooth mechanism 2 that can be freely tied together, a hanger member that is attached to the upper part of the pipe string and has a downward supporting surface that engages the shoulder of the seat member; The hanger member KIM is cut around the port fk#
lI and all preparations, front d support surface and cocoon d self! 6601. A hanging device characterized in that the four parts are configured to be able to spread around the entire circumference of 6601. (124) A feature Wl characterized in that the primary support surface has an annular support portion with an attachment/detachment mark that is screwed into the hanger member.
The hanging device according to item 123 of f-Ku no Horoma. (125) The III device has a plurality of grooving teeth provided with a wall between them, and the grooving teeth of the seat member are such that the seat member is pushed into the well hept member. 4'! When the well head member is inserted into the well head member, it should pass between the grooving teeth of the well head member. ? 125. A hanging device according to claim 125. (126) Each tooth of the IIt mechanism is spaced apart from each other to form a leadless screw, and engages in a non-interfering manner when the seat member is rotated within the well head member, and The hanging device according to item 125, which is configured as follows. (127) The hanger member has a shape Qi7 on both sets of well head members above the support surface. Claim 126, characterized in that a latch member is provided in the fixed hole 71 and extends and protrudes so that the hanger member can be fixed within the well head member.
Suspension device as described in section. (128) Is the hanger member provided with a sealing mechanism? J, MS/-LE 5tFi each alternately frustonical ms,, (fruatoonical) #I
These gold 54-! j, the outer diameter of the ring is smaller than the inner diameter of the well head member, and the *XIII ring row has a sliding wall 191 that applies axial force to the * is connected to the hanger member from the I/f! Claim 123, characterized in that the metal-to-metal seal engagement with the well hood member is provided in claim 123. (129) ll11! The hanger member is characterized in that it forms a shoulder in the shape of #'lt and is provided with an actuating member capable of being agitated, and the metal ring row is disposed between the shoulder and the IIIJ actuating member. Patent claim complaints 128
Suspension device as described in section. (t5o) A beak-shaped link is provided between the Iff ring, the I part, and the operating member, and the part and the actuator are connected to each other. 129. The hanging device according to item 129, characterized in that a positive connection link is formed between the IEl1g6 material and the IEl1g6 material. (131) The metal ring described in ltJ is characterized in that each of the metal rings forms a clear hole for accommodating an elastic sealing material with the adjacent metal ring. Device described in the section. (132) @ The hanging device according to claim $13Or4, wherein α-F indicates that a spacer IPs is provided between the metal rings that meet each other. (155) A pressure seal fk that is provided on the hanger member and is disposed within an annular portion formed between the hanger member and the well head member, and is activated when a vertical compressive force is applied.
4slf, screwed onto the hanger member and partially connected to the VCVi.
a working member having an engagement portion with the suppression sealing mechanism, and engaging the working member and transmitting rotation to the working member to align the operating member with the hanger member and move it downward; In addition, press and seal the structure → apply a vertical compressive force to the structure, add an additional vertical compressive force to the structure,
125. The device as described in claim 125, further comprising a hydraulic mechanism for applying energy to the pressure writing mechanism to operate it. (1!54) The well head member, the hanger member, the first hanger member (attached light), the second hanger member, and the metal-to-metal V-ru between the second hanger member and the well head member. A second metal-to-metal V-le barrel structure forming a second metal V-ru barrel structure, and a second hanger member KIlv attached to the chick 3
A patent characterized in that it is provided with a hanger member and a third metal scrap metal V-route structure forming a metal-to-metal V-ru between the third hanger member and the well head member. The hanging device according to item 123 of the claim. (1!55) IIIE first metal to metal V-ru structure and the 1g2 metal to metal V-ru 4]!1 structure and the fifth metal pair a torque transmission mechanism that engages with the metal V-ru a4#/I in a continuous manner to apply a vertical compressive force to these mechanisms; the first metal-to-metal V-ru pattern; and the second Claim 134, further comprising a hydraulic mechanism that applies hydraulic pressure to the metal-to-metal seal structure and the third metal V-ru structure to further engage them. (156) A method for completing a well below the sea surface, including the step of locating a drill mechanism at the wellbore position of 7II-suspension, and the step of: and a step of installing the blowout prevention stack and the live pipe extending toward the drill mechanism in a position close to the seabed;
passing a drill string and a drill bit through the well head and the conductor casing; drilling a hole inside the well head and the conductor casing for suspending another casing; and a hanger seat. lowering the hanger seat into the wellbore until it is supported by the well head; rotating the hanger seat by 560" or less to couple it into the well head; fixing the hanger seat within the 11111i3 well head; A method for completing a wellbore, comprising the steps of: guiding a casing hanger that supports another casing through a casing riser and into a 11 casing head; and attaching the casing hanger to the hanger seat. (137) A ninth method for finishing a well below 1m, including the step of locating a drill mechanism at the wellbore location below the sea surface, and placing a conductor casing on the seabed with the well head, blowout prevention stack, and the drill mechanism. a step of attaching a riser extending in the F direction toward the well head and the conductor casing in a state close to the seabed; a step of attaching a drill string and a drill bit to the well head and the conductor casing;
＃The process of drilling a hole for hanging the casing inside the well head and conductor casing, and the process of drilling a hole for hanging the casing inside the conductor casing, and installing a light hanger with chain wood screws, By lowering the wellbore until it engages with the upper part of the closing screw of the head, and by rotating the # marked hanger one revolution or less, the closing teeth of the hanger seat are inserted between the mill teeth of the well head. a step of moving the hanger seat slightly downwardly with respect to the well head through a step of rotating the 11riB hanger seat by one rotation or less to connect it within the well head, and a step of moving the casing hanger supporting the casing dust ring into the well head. A method for completing a wellbore, comprising the steps of: guiding the casing through the hole into the wellhead; and attaching the casing hanger to the bunker. (1! $8) A method of completing a well below sea level, in which a conductor casing is placed on the seabed with a well head, a blowout prevention stack, and a riser that extends upward to the sea surface. The installation process and case V
passing a casing hanger supporting a dust ring through the live, installing the casing hanger into the well head, and rotating an actuating ring provided above the sealing mechanism and screwed into the casing hanger. The process...! Compressing the 111th seal mechanism by lowering the actuating ring along the casing hanger and compressing the 111st seal mechanism by lowering the actuating ring along the casing hanger; A type of work that can reduce the cone angle of all U-1f,
A step of pressurizing the elastic member that has been accommodated between the metal rings as the cone angle decreases, and by compressing the elastic member, the well head and the casing hanger are freed from the fluid. and a step of applying the hydraulic pressure to the well head, and as the sealing mechanism is further compressed by this hydraulic pressure, the inner and outer ends of the ring are connected to the well head and the hydraulic pressure. /
A method for completing a wellbore, comprising: a step of repelling the contact; and the operation of the sealing mechanism as the sealing mechanism is further compressed by hydraulic pressure. (140) A method for completing a wellbore under mItI, which includes a factory for connecting an end K11L tool of a drill string, a step of quickly connecting the through tool to a casing hanger, and a step of connecting the casing hanger #l to the above. guiding the casing hanger along with the casing dust ring into the well head through the casing and blowout prevention stack; and placing the casing hanger on the shoulder of the well head. 11r, rotating the replacement string and a part of the release tool; applying torque to the actuation nut through the part of the thread; and screwing the actuation nut into the casing hanger. compressing the V-ru mechanism under the actuating nut; forming a resilient seal between the well head and the casing/one ring through the V-ru mechanism; - applying a torque to the drill string when the torque transmitted to the drill mechanism reaches a limit; closing a blowout prevention knob of the blowout prevention stack; and an annular portion between the drill string and the well head. and a step b of applying pressure to the passage leading to the lower part of the blowout prevention stack, a step of applying hydraulic pressure to the V-ru mechanism, and a frustonic (frugt
ooonioal) shaped vase casket 11
forming a metal-to-metal V-ru between the 9'''' and the front 11B+''-7'hangers;
The process of rotating the operating nut and further lowering it along the m-th cable V hanger as the MtlF-ring mechanism is applied with hydraulic pressure of 1l-fN, and the hydraulic pressure to the #1 distribution link. A method for completing a wellbore, comprising the steps of: releasing the Wa marking tool from the casing hanger, removing the Wa marking tool from the casing hanger, and removing the Wa marking tool from the wellbore. (141) The method for completing a wellbore according to claim 140, which includes the step of lifting the drill string and removing the threading tool from the casing hanger. (142) The threading tool can be attached and detached from the casing hanger K
The installation method for attaching the W
(11) moving the indolyl of the threading bird downward within the sleeve; energizing a latch provided on the sleeve to engage the casting case; and retaining the latch by the mandrel. Letter II! passing the casing hanger supporting the casing string into the wellbore; placing the casing hanger on the well head; further lowering the mandrel within the sleeve; moving the biasing portion of the mandrel from the latch; raising the mandrel; and II, once the mandrel has been raised excessively, the steps of coupling the sleeve to the mandrel prior to energizing the latch, disengaging the latch from engagement with the casing hanger, and removing the pre-threader from the wellbore. How to install. () Large”) = Missing 1 = Glue.Fu